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MINISTRY OF
INDUSTRY AND TRADE
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SOCIALIST REPUBLIC
OF VIETNAM
Independence - Freedom - Happiness
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No.: 30/2014/TT-BCT
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Hanoi, 02 October,
2014
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CIRCULAR
PROVIDING
FOR OPERATION OF COMPETITIVE ELECTRICITY GENERATION MARKET
Pursuant to Decree No. 95/2012 / ND-CP dated
12 November, 2012 of the Government defining functions, tasks, powers and
organizational structure of the Ministry of Industry and Trade;
Pursuant to the Electricity Law dated 3
December 2004; the Law amending and supplementing a number of articles of the
Electricity Law dated 20 November, 2012;
Pursuant to Decision No. 63/2013/QD-TTg dated 08
November 2013 of the Prime Minister providing for the roadmap, conditions and
structure of electricity industry to form and develop levels of electricity
market in Vietnam;
At the request of the Director of Electricity
Regulatory Authority of Vietnam;
The Ministry of Industry and Trade issues the
Circular providing for the operation of competitive electricity generation
market.
Chapter I
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Article 1. Scope of
regulation
This Circular provides for the operation of
competitive electricity generation market (hereafter referred to as electricity
market) and the responsibilities of Units participating in electricity market.
Article 2. Subjects
of application
This Circular applies to the following Units participating
in electricity market:
1. Single wholesaling Units .
2. Electricity generating Units
3. Electricity system and market operating
Unit
4. Electricity transmitting Units.
5. Power metering data managing Units.
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Article 3. Interpretation
of terms
In this Circular, the terms below are
construed as follows:
1. Price quotation is the quotation of power
sale in the electricity market of each generating set. This quotation is
submitted by the price offering Units to the electricity system and market
operating Unit under the form of price quotation specified in this Circular.
2. Scheduling price quotation is the one
accepted by the electricity system and market operating Unit for next hour and
day scheduling.
3. Payment list is the calculation table of
payments to the power plant directly participating in the electricity market.
This list is made by the electricity system and market operating Unit for each
transaction day and for each payment cycle.
4. Intervention in the electricity market is
the act to change the normal operational mode of the electricity market which
the electricity system and market operating Unit must apply to deal with
circumstances specified in Clause 1, Article 59 of this Circular.
5. Transaction cycle is the period of one
hour from the first minute of each hour.
6. Payment cycle is the one to prepare invoices
and vouchers for transactions in the electricity marketing the period of one
month, from the 1st date of each month.
7. Announced capacity is the available
highest capacity of the generating set announced as per the schedule of
electricity market by the price offering Units or the electricity system and
market operating Unit and the electricity generating Units signing the auxiliary
services announced as per the electricity market operation schedule.
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9. Mobilized capacity for next hour is the
capacity of the generating set planned for mobilization for the first hour in
the mobilization schedule for next hour.
10. Mobilized capacity for next hour is the
capacity of the generating set planned for mobilization for the first hour in
the mobilization schedule for next hour as per the constrained scheduling
result.
11. Increasingly generated capacity is the
difference of capacity between the dispatching capacity and the capacity arranged
in the market price calculation schedule of the generating set.
12. Paid capacity is the capacity of generating
set included in the hourly capacity schedule and is paid the market capacity
price.
13. Auxiliary services mean the frequency
adjustment, rotation standby, quick start standby, cold standby, operation to
be generated due to constrained security of electricity system, voltage
adjustment and black start
14. Increasingly generated power is the power
generated by the generating set thanks to mobilization corresponding to the increasingly
generated capacity.
15. Price offering Units mean the ones
directly submitting the price quotation in the electricity market, including
the electricity generating Units or power plants that register direct price offer
and representative Units of price offer for group of ladder hydropower plants.
16. Single whosaling Unit is the single
electricity buying Units in the electricity market, having function to buy all
power through the electricity market and under electricity sale contract.
17. Electricity generating Unit is the Units
owning one or many power plants participating in the electricity market and
signing the electricity sale contract for such power plants with the single
wholesaling Units .
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19. Electricity generating Units directly
doing transaction are the electricity generating Units having power plant
entitled to direct price offer in the electricity market.
20. Power metering data managing Unit is the
one providing, installing, managing the operation of system collecting,
processing and storing the power metering data and network of communication
line in service of electricity market.
21. Electricity transmitting Unit is the
electricity Units licensed for electricity activities in the field of
electricity transmission, responsible for managing and operating the national
transmission grid.
22. Electricity system and market operating Unit
is the Unit directing and controlling the process of electricity generation,
transmission and distribution in the national electricity system and operating
the transaction of electricity market.
23. Market capacity price is the price for
one Units of active capacity determined for each transaction cycle to be
applied for calculating the payment of capacity to the electricity generating Units
in the electricity market.
24. Price floor of quotation is the lowest
price which the price offering Units is entitled to offer for one generating
set in the price quotation for next day.
25. Market power price is the price for one Units
of power determined for each transaction cycle to be applied for calculating
the payment of power to the electricity generating Units in the electricity
market.
26. Full electricity market price is the
total electricity market price and market capacity price of each transaction
cycle.
27. Price ceiling of quotation is the highest
price which the price offering Units is entitled to offer for one generating
set in the price quotation for next day.
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29. Water value is the marginal price to
expect the calculation for the water amount reserved in reservoirs when used to
generate power in lieu of electrothermal in the future as converted to a power Units.
30. Performance degradation coefficient is
the performance degradation index of the generating set as per operational
time.
31. Monthly or annual average load factor is
the is the ratio between the total power generated in 01 year or 01 month and the
product of the total installed capacity with the total calculation hour of
annual or monthly load factor.
32. Information system of electricity market
is the system of equipment and database for management and exchange of
information on electricity market which the electricity system and market
operating Unit manages.
33. Electricity sale contract is the written
agreement on electricity sale between the single wholesaling Units and the electricity
generating Units or trading of electricity with foreign countries.
34. Electricity sale contract for difference
is the electricity sale contract signed between the single wholesaling Units with
the electricity generating Units with directly doing transaction under the form
issued by the Ministry of Industry and Trade.
35. Constrained scheduling is the collocation
of mobilization of generating Units by the least-cost method of electricity
purchase taking into account the technical constraint in the electrical system.
36. Unconstrained scheduling is the
collocation of mobilization of generating Units by the least-cost method of
electricity purchase not taking into account the technical constraint in the
electrical system.
37. Capacity schedule is the schedule
prepared by the electricity system and market operating Unit after operation to
determine the amount of paid capacity in each transaction cycle.
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39. Mobilization schedule for next day is the
Estimated schedule of generating sets for electricity generation and supply of
auxiliary services to the next transaction cycle and three consecutive cycles
set by the electricity system and market operating Unit.
40. Market electricity price calculation
schedule is the one set by the electricity system and market operating Unit
after the current transaction day to determine the market power price for each
transaction cycle.
41. Electricity market simulation model is a
system of softwares simulating the mobilization of generating sets and
calculating the market power price which the electricity system and market
operating Unit uses for weekly, monthly and annual operational plan.
42. Water value calculation model is a system
of sotwares optimizing the hydrothermal power to calculate the water value
which the electricity system and market operating Unit uses for weekly, monthly
and annual operational plan.
43. Limited water level is the lowest
upstream water level of reservoir at the end of each month in a year or at the
end of week in a month which the electricity system and market operating Unit calculates
and announces under the Procedures for short and medium-term assessment of
electricity system security issued by the Electricity Regulatory Authority on
the implementation of Regulation on power transmission system issued by the
Ministry of Industry and Trade.
44. Optimal water level is the upstream water
level of reservoir at the end of each month or week, ensuring the use of water
for the most effective electrical generation and meeting the constrained
requirement calculated and announced by the electricity system and market
operating Unit.
45. Year N is the current year of electricity
market operation by solar calendar.
46. Day D is the current transaction day.
47. Transaction day is the day when there are
electricity transaction activities, from 1:00 AM to 12:00 PM everyday.
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49. Best new power plant is the thermal power plant just put into operation with the
lowest electrical generation price calculated for the next year and the price
of electricity sale contract is agreed based on the price bracket of electrical
generation for the standard power plant issued by the Ministry of Industry and
Trade. The best power plant is selected annually for use in calculating the
market capacity price.
50. Multi-objective strategic hydropower
plants are the big power plants playing an important role on economy, society,
national defense and security. These power plants are built and operated by the
state exclusively.
51. Group of ladder hydropower plants is the
set of hydropower plants in which the amount of water discharged from the
reservoir of the upper ladder hydropower plants makes up all or most of the amount
of water to the reservoir of the lower hydropower plants and there is no
reservoir with regulation capability of more than 01 week between these two
reservoirs.
52. Scheduling software is the software
system which the electricity system and market operating Unit uses for the mobilization
scheduling for next day and hour to the generating sets in the electricity market.
53. System load is the total power output of
the whole electrical system converted at the terminals of generating sets and
the imported power output in a transaction cycle minus the output of power
plants with installed capacity less than or equal to 30 MW not participating in
the electricity market and the output of ladder hydropower plants in the same
river under the ownership of one electricity generating Units with the
installed capacity less than or equal to 60 MW (meeting the standard to apply
the avoided cost tariff).
54. Metered output is the power of power
plant which can be metered at the metering location.
55. Hourly contract output is the power
output allocated for each transaction cycle and paid under the electricity sale
contract for difference.
56. Yearly contract output is the yearly
committed power output in the electricity sale contract for difference.
57. Monthly contract output is the power
output allocated from the yearly contract output for each month.
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59. Monthly planned output is the power
output of power plant Estimated to be mobilized for the months in a year.
60. Heat rate is the amount of lost thermal
energy of the generating set or power plant to produce one Units of power.
61. Constrained generation payment is the
payment received by the electricity generating Units for the increasingly
generated power.
62. Participants of electricity market are Units
participating in the transaction activities or providing services in the
electricity market specified in Article 2 of this Circular.
63. Month M is the current month of
electricity market operation calculated by solar month.
64. Capacity shortage is a situation when the
total announced capacity of all electricity generating Units is less than the
load demand of forecasting system in a transaction cycle.
65. Confidential information is secret
information as stipulated by law or agreed by the parties.
66. Market information is the entire database
and information related to the activities of electricity market.
67. End time of price offering is the time
after which the electricity generating Units are not permitted to change the
price quotation for next day, except for special cases stipulated in this
Circular. In the electricity market, the end time of price offering is 11:30 PM
of day D-1.
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69. Excessive capacity is a situation when
the total capacity offered at ceiling price of the electricity generating Units
directly doing transaction and the capacity Estimated to be mobilized of the power
plants owned by electricity generating Units indirectly doing transaction. The electricity
system and market operating Unit shall announce it in the transaction cycle
greater than the load of forecasting system.
70. Total hours of yearly load factor calculation
is the total hours of the entire year N for the generating sets which have been
put into commercial operation from year N-1 and earlier or the total hours from
the time of commercial operation of the generating set by the end of year for
the generating sets put into commercial operation in year N minus the repair
time of generating set under the approved plan in year N.
71. Total hours of monthly load factor
calculation is the total hours of the entire month M for the generating sets
which have been put into commercial operation from year M-1 and earlier or the
total hours from the time of commercial operation of the generating set by the
end of month for the generating sets put into commercial operation in month M
minus the repair time of generating set under the approved plan in month M.
72. Slow-started generating set is a generating
set uncapable of starting and connected with power grid in a time of less than
30 minutes.
73. Week T is the current week of electricity
market operation.
74. Metering location is the location where
the power metering system is placed to determine the delivered power output for
payment of electricity market between the electricity generating Units and the single
wholesaling Units under the provisions in Circular No. 27/2009/TT-BCT dated 27
September 2009 stipulating the power metering in the competitive electricity
generation market and under the electricity sale contract between the electricity
generating Units and the single wholesaling Units .
Chapter II
REGISTRATION
FOR PARTICIPATION IN ELECTRICITY MARKET
Article 4.
Responsibility for participation in electricity market
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2. The power plants having the installed
capacity up to 30 MW connected to the grid with voltage of 110 Kv or higher,
except for the power plants specified in Clause 3 of this Article have the
right to opt for participation in electricity market. In case of option for
participation in electricity market, such power plants must meet the following
requirements:
a) Preparing infrastructure under the
provisions in Clause 5 of this Article;
b) Completing and submitting dossier of
registration of electricity market as stipulated in Clause 2 and 3, Article 5
and Clause 1, Article 6 of this Circular;
c) Complying with the requirements for the electricity
generating Units participating in electricity market under the provisions of
this Circular and the relevant legal normative documents.
3. The power plants which do not participate
in the electricity market include:
a) BOT power plants;
b) Power plants using non-hydroelectric
recycling energy;
c) Power plants in the industrial parks only
sell a part of output onto the national electricity system without determining
their long-term electricity sale plan.
4. Before 01 November of year N-1, the electricity
system and market operating Unit must report to the Electricity Regulatory
Authority on the list of electricity generating Units directly and indirectly
doing transaction and the electricity generating Units not participating in the
electricity market under the provisions in Clause 3 of this Article in year N
for announcement to the participants of electricity market.
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6. Where the power plants have met all
conditions but not participated in the electricity market as stipulated in
Clause 1 of this Article:
a) Before 25th date of each month,
such power plants must send report to the Electricity Regulatory Authority and
the electricity system and market operating Unit, the single wholesaling Units on
investment and completion progress of items to meet the operational
requirements of electricity market;
b) The electricity system and market
operating Unit must continue to schedule and announce the capacity mobilization
chart for the power plant;
c) The power plants have been temporarily
paid the whole actual output generated in the payment cycle at the price equal
to 90% of that of electricity sale contract signed between the two parties. The
difference of electricity payment (10% remaining) is settled in the payment
cycle of the first month when the plants directly participate in price offering
in the electricity market.
Article 5. Dossier of
registration for participation in electricity market
1. Before 02 (two) months from the deadline
to participate in the electricity market under the provisions in Clause 1,
Article 4 of this Circular, the electricity generating Units must complete their
dossiers of registration for participation in electricity market for
each power plant.
2. Dossier of registration for participation
in electricity market include:
a) Registration for participation in
electricity market specifying name, address of the electricity generating Units
and the power plant;
b) A copy of electricity operation License in
the field of electricity generation.
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d) Other necessary information as provided
for in the Procedures for registration for participation in electricity market
issued by the Electricity Regulatory Authority.
3. Number of dossier: 02 (two) sets.
Article 6. Approving dossier
of registration for participation in electricity market
1. The electricity generating Units must
submit dossier of registration for participation in electricity market for each
power plant to the Electricity Regulatory Authority directly or by post.
2. The Electricity Regulatory Authority shall
receive dossiers, check their completeness and guide the completion of dossier
(if directly submitted) or within 02 working days after receipt of dossier (if
receiving dossier by post).
3. Within 02 working days after receipt of
complete dossier, the Electricity Regulatory Authority shall send a set of
dossier to the electricity system and market operating Unit.
4. Within 05 working days after receipt of dossier
of registration for participation in electricity market, the electricity system
and market operating Unit shall give feedback in writing to the Electricity
Regulatory Authority on the confirmation of capability and moment to
participate in the electricity market of the power plant.
5. Within 05 working days after receipt of
document from the electricity system and market operating Unit, the Electricity
Regulatory Authority shall verify the dossiers:
a) If the dossier is valid, the Electricity
Regulatory Authority shall issue a decision on approving the electricity market
directly or by post to the electricity generating Units and notify the electricity
system and market operating Unit;
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- The Electricity Regulatory Authority shall
send the electricity generating Units the document stating the invalidity of
dossier and request the electricity generating Units to explain and complete
their dossiers;
- Within 05 working days after the electricity
generating Units receives the written request, the electricity generating Units
shall send the Electricity Regulatory Authority the written explanation and
completed dossier;
- Within 03 working days after receiving the
written explanation and the completed dossier of the electricity generating Units,
the Electricity Regulatory Authority shall verify the dossiers under the provisions
in this Clause.
Article 7.
Information on participants of electricity market
1. The electricity transmitting Units, the single
wholesaling Units and the power metering data managing Units must register the
general information on their Units to the electricity system and market
operating Unit.
2. The electricity system and market
operating Unit shall store the registered information and update changes of
registered information of the electricity market participants.
3. The electricity market participants must
inform the electricity system and market operating Unit upon changes of
registered information.
4. The electricity system and market
operating Unit shall announce the registered information of electricity market
participants and the changed registered information.
Article 8. Suspending
and restoring the right to participate in electricity market of power plant
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a) Failing to completely comply with the
provisions specified in Clause 5, Article 4 of this Circular;
b) Having one of the acts of violation as
follows:
- Failing to provide information or provide
correct information for the operational plan for electricity market and
mobilization schedule of generating sets in the electricity system;
- Failing to provide information or provide
correct information for the settlement of dispute and handling of violation in
the competitive electricity market under regulations of law.
- Making direct or indirect agreement with
other Units in limiting or controlling the offering capacity in the market in
the order to increase the spot price of market electricity and affect the
security of electricity supply;
- Making agreement with other electricity
generating Units in price offering for mobilization scheduling;
- Making agreement with the electricity
system and market operating Unit in price offering for improper mobilization
scheduling;
- Other acts of violation causing serious
consequences for ensuring the security of electricity supply or finance to
other Units in the electricity market.
2. The Electricity Regulatory Authority has
the right to suspend the right to participate in the electricity market of any
power plant having acts of violation specified in Clause 1 of this Article. The
order and procedures for suspension are specified in Article 113 of this
Circular.
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a) The electricity generating Units or the
power plant must not offer price directly in the electricity market but must
comply with other provisions of this Circular;
b) The electricity system and market
operating Unit must set up the schedule and announce the capacity mobilization
chart for the plants whose right to participate in the electricity market is
suspended. Such plants shall be paid all actual output generated in the payment
cycle at the price equal to 90% of that of electricity sale contract signed
between the two parties. The difference of electricity payment (10% remainder)
is settled in the payment cycle of the first month when the plants is restored
its right to participate in the electricity market.
4. The suspended plant whose right to
participate in the electricity market is restored when meeting the following
conditions:
a) When the time limit for suspending the
right to participate in the electricity market;
b) Having completed the obligations specified
in the decision on suspending the right to participate in the electricity
market;
5. When having met the conditions specified
in Clause 4 of this Article, the power plant must send document to request the
restoration of its right to participate in the electricity market and also send
evidencing documents to the electricity system and market operating Unit which
shall verify them and report to the Electricity Regulatory Authority on
permitting the power plant to participate in the electricity market.
6. Where the time limit for suspending the
right to participate in the electricity market is over but the power plant has
not met all conditions specified under Point b, Clause 4 of this Article, the electricity
system and market operating Unit shall report to the Electricity Regulatory
Authority for consideration and handling.
Article 9.
Terminating the participation in electricity market
1. The power plant shall terminate its
participation in electricity market in the following cases:
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- The power plant of the electricity
generating Units has fully stopped its operation;
- The power plant of the electricity
generating Units fails to maintain and is unable to restore its installed
capacity greater than 30 MW within 01 year.
b) The electricity operation license in the
field of electric generation of the power plant is revoked or expired.
2. In cases specified under Point a, Clause 1
of this Article, the electricity generating Units owning the power plant must
submit dossier to request the termination of participation in electricity
market to the electricity system and market operating Unit and the Electricity
Regulatory Authority for consideration within 30 days before the time of
termination of participation in electricity market.
3. The electricity system and market
operating Unit must update dossiers and store registration information and announce
information on termination of participation in electricity market.
4. Where the power plant commits acts of
violation before the time of termination of participation in electricity market,
the electricity generating Units owning such power plant must continue the
implementation of regulations on verification and handling of violation as
stipulated in this Circular.
Chapter III
PRINCIPLES
OF ELECTRICITY MARKET OPERATION
Article 10. Limit of
offered price
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2. The price ceiling of quotation of the
thermoelectric Units is determined annually and adjusted monthly and calculated
based on the following factors:
a) Heat rate of generating set;
b) Performance degradation coefficient as per
the operational time of generating set;
c) Price of fuel;
d) Coefficient of auxiliary expenses;
dd) Price varying under electricity sale
contract.
3. Price floor of thermoelectric set is 01
dong/kWh.
4. Limit of offered price of generating sets
is specified in Article 10 of this Circular.
Article 11. Water
value
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2. The electricity system and market
operating Unit shall calculate and announce the water value as per the electricity
market operation schedule specified in Annex 1 of this Circular.
Article 12. Full
market price
The full market price for the transaction
cycle is calculated by the sum of 02 (two) components as follows:
1. Price of market power
2. Price of market capacity.
Article 13. Price of
market power
1. The price of market power is calculated by
the electricity system and market operating Unit after the operational time
based on the unconstrained scheduling method.
2. The price of market power must not exceed
the market price ceiling which is calculated by the electricity system and
market operating Unit and approved by the Electricity Regulatory Authority
annually.
3. The determination of price of market power
is specified in Article 67 and 69 of this Circular.
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1. The price of market capacity for each
transaction cycle is calculated by the electricity system and market operating
Unit during the operational planning for next year and there is no change in
the applied year.
2. The price of market capacity is calculated
on the principle of ensuring that the best new power plant recovers its
variable and fixed costs sufficiently.
3. The determination of price of market
capacity is specified in Article 25 and 26 of this Circular.
Article 15.
Electricity sale contract for difference
1. The electricity generating Units directly
doing transaction and the single wholesaling Units are responsible for signing
the electricity sale contract for difference under the form issued by the
Ministry of Industry and Trade.
2. The yearly contract output is calculated
by the electricity system and market operating Unit based on the yearly planned
output and the ratio of paid output at the contract price specified in Clause 5
of this Article. The annual planned output is calculated by the electricity
system and market operating Unit during the operational planning for next year
as stipulated in Clause 2, Article 27 of this Circular.
3. The monthly contract output is determined
by the electricity system and market operating Unit during the operational planning
for next year based on the allocation of yearly contract output in the months
specified in Article 28 of this Circular.
4. The hourly contract output is determined
by the electricity system and market operating Unit during the operational planning
for next month based on the allocation of monthly contract output at the hours
in months specified in Article 37 of this Circular.
5. The Electricity Regulatory Authority shall
determine and announce the percentage of paid output at the contract price of
the electricity generating Units each year depending on each technology model on
the following principles:
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- Encouraging the effective competition in
the electricity market;
- Stabilizing revenues of the electricity
generating Units;
- Stabilizing the average price of
electricity generation in accordance with regulation capabilitys on setting the
electricity retailing quotation.
b) The percentage of power output paid at the
contract price is specified separately for different types of hydro and thermal
power. This percentage must not higher than 95% and lower than 60%.
Article 16. Principle
of payment in electricity market.
1. The electricity generating Units directly
doing transaction is paid at the electricity market price and under the
electricity sale contract for difference.
2. The payment at market price is applied
only to the electricity generating Units directly doing transaction and is
calculated based on the following factors:
a) Price of market power;
b) Price of market capacity;
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3. The payment for the electricity generating
Units directly doing transaction is done as stipulated in Chapter VI of this
Cicular.
4. The electricity generating Units
indirectly doing transaction is paid under the provisions in the electricity
sale contract.
Chapter IV
OPERATIONAL
PLAN OF ELECTRICITY MARKET
Section 1:
OPERATIONAL PLAN FOR NEXT YEAR
Article 17. Operational
plan for next year
1. The electricity system and market
operating Unit shall make the operational plan for electricity market for next
year, including the following contents:
a) Choosing the best new power plant;
b) Calculating the price of market capacity;
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d) Calculating the limit of price in
quotation of the thermoelectric set;
dd) Determining the plan of market price
ceiling;
e) Taking charge and coordinating with the single
wholesaling Units to calculate the planned output, yearly contract output and
allocate the annual contract output to the months in a year of the electricity
generating Units directly doing transaction.
2. The electricity system and market
operating Unit shall use the electricity market simulation model to calculate
the contents specified under Points a, b, c, d and dd, Clause 1 of this
Article. The input parameters used in the market simulation of the
thermoelectric sets are variable cost of the generating set and are specified
in Clause 3 of this Article. The hydrological features and specifications of
hydropower plants.
3. The variable cost of the thermoelectric
set is determined as follows :
a) Where the value of heat rate is determined,
the variable cost of generating set is determined as follows:
In which:
VC: Variable cost of thermoelectric set
(dong/kWh);
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HR: Heat rate of thermoelectric set (BTU/kWh or
kCal/kWh);
- Fuel price (PNL) is the Estimated
fuel price for year N provided by the single wholesaling Units for the electricity
system and market operating Unit.
The fuel price of year N is the fuel price announced
by the competent authorities for year N or in the long-term primary fuel sale contract.
Where there are both two prices mentioned above, the fuel price announced by
the competent authorities for year N is used. Where there is no both two prices
mentioned above, the fuel price of year N is calculated by the average of
actual fuel price used for payment of the last 12 months before the time of
operational planning for year N;
- The heat rate of thermoelectric set (HR) is
determined by the heat rate agreed in the contract or in dossier of negotiation
of electricity sale contract provided by the single wholesaling Units and
adjusted by the coefficient of performance degradation. Where the heat rate in
the contract is the average heat rate of life of contract, it is not necessary
to adjust it as per the coefficient of performance degradation. If in the
contract or in dossier of negotiation of electricity sale contract, there is
only a characteristic curve of capacity loss at the load levels, the heat rate
of the generating sets is determined at the load level corresponding to the
average power output generated in many years of the power plant specified in
the electricity sale contract.
Where the thermoelectric set has no data of heat
rate in the contract or in dossier of negotiation of electricity sale contract,
the heat rate of such power plant is determined by the heat rate of standard
power plant of the same group with the technology of electrical generation and
installed capacity. The electricity system and market operating Unit calculates
the heat rate of standard power plant.
- The coefficient of performance degradation
of the thermoelectric set is determined by the heat rate in the contract or in dossier
of negotiation of electricity sale contract provided by the single wholesaling
Units .
Where the thermal power plant has no data of
coefficient of performance degradation in the contract or in dossier of
negotiation of electricity sale contract, apply the coefficient of performance
degradation of standard power plant of the same group with such power plant
which the electricity system and market operating Unit has determined;
- Coefficient of additional cost (f) of the
thermoelectric set which the single wholesaling Units has determined and and
provided for the electricity system and market operating Unit based on the data
in the electricity sale contract or dossier of negotiation of electricity sale
contract. Where the coefficient of additional cost of the thermoelectric set is
not included in the contract or dossier of negotiation of electricity sale
contract, the the coefficient of additional cost of such thermoelectric set is
determined according to the Regulation on method of setting of price of
electrical generation; order and procedures for verifying the electricity sale
contract which the Ministry of Industry and Trade has issued;
b) Where there is no data of heat rate in the
contract or in dossier of negotiation of electricity sale contract and no
standard power plant of the same group, the variable cost of the generating set
is determined by the variable price in the contract with update of factors
affectin the variable price of year N by the method agreed in the contract.
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5. Where the price of coal and gas for electrical
generation changes largely compared with the time of approving the operational
plan for next year, the Electricity Regulatory Authority shall review and
request the electricity system and market operating Unit to update the data and
re-calculate the operational plan for the remaining months in the year and
submit to the Vietname Electricity for appraisal and to the Electricity
Regulatory Authority for approval.
Article 18.
Classification of power plant
1. The power plants in the electricity market
is classified as follows:
a) Multi-objective strategic hydropower
plants;
b) Group of ladder hydropower plants;
c) Group of hydropower plants having
reservoir with regulation capability of more than 01 week;
d) Group of hydropower plants having
reservoir with regulation capability from 02 days to 01 week;
dd) Group of hydropower plants having
reservoir with regulation capability of less than 01 week;
2. Every year, the electricity system and
market operating Unit must update the list of hydropower plants specified in
Clause 1 of this Article.
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Article 19. Load
forecasting for the operational planning for next year
The electricity system and market operating
Unit must forecast the load for the operational planning for next year by the
method specified in the Regulation on power transmission system issued by the
Ministry of Industry and Trade. The data of load forecasting for the planning
of operation for next year include:
1. The total demand for load of national
electricity system and load of the North, Central and South for the entire year
and each month in a year.
2. The load chart of typical days of the
North, Central and South and the whole of national electricity system of months
in a year.
3. Maximum and minimum capacity of load of
national electricity system in each month.
Article 20. Auxiliary
services for operational plan for next year
1. The electricity system and market
operating Unit must determine the demand for auxiliary services for next year
under the provisions in the Regulation on power transmission system issued by
the Ministry of Industry and Trade.
2. The electricity system and market
operating Unit must choose the power plant to provide the auxiliary services.
The power plant chosen shall provide the auxiliary services and be paid as
stipulated by the Ministry of Industry and Trade.
Article 21.
Classification of generating set with base load for next year, intermediate
load and peak load
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2. The electricity system and market operating
Unit shall use the electricity market simulation model to determine the annual
average load factor of generating sets.
3. Based on the annual average load factor
from the simulation result, the generating sets are classified into 03 (three)
groups as follows:
a) Group of generating set with base load
includes the generating set with annual average load factor greater or equal to
60%;
b) Group of generating set with intermediate
load includes the generating set with annual average load factor greater than 25%
and less than 60%;
c) Group of generating set with peak load
includes the generating set with annual average load factor less than or equal
to 25%;
Article 22.
Determining the limit of offered price of generating set
1. In case of determination of value of heat
rate:
a) The price ceiling of quotation of
thermoelectric set is determined by the following formula:
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: Price ceiling of quotation of
thermoelectric set (dong/kWh);
f: Coefficient of additional cost is
calculated by the percentage of total start cost, fuel-secondary material cost
and variable maintenance and operation cost for generation compared with main
material cost;
KDC: Adjustment
coefficient of price ceiling as per the classification result of thermoelectric
set. For the thermoelectric set with base load KDC = 2%;
thermoelectric set with intermediate load KDC = 5%; KDC
= 5%; the thermoelectric set with peak load KDC = 20%.
PNL: Price of main fuel
of thermoelectric set (dong/kCal or dong/BTU);
HR: Heat rate at the average load of
thermoelectric set (BTU/kWh or kCal/kWh);
b) The parameters on coefficient of
additional cost (f), fuel price (PNL) and heat rate (HR) of
the thermoelectric set are determined as stipulated under Point a, Clause 3,
Article 17 of this Circular.
2. Where there is no data of heat rate in the
contract or dossier of dossier of negotiation of electricity sale contract and
there is no standard power plant of the same group :
a) The price ceiling of quotation of
thermoelectric set is determined by the following formula:
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: Price ceiling of thermoelectric set (dong/kWh);
KDC: Adjustment
coefficient of price ceiling as per the classification result of thermoelectric
set. For the thermoelectric set with base load KDC = 2%;
thermoelectric set with intermediate load KDC = 5%; KDC
= 5%; the thermoelectric set with peak load KDC = 20%.
: Variable price for year N under the
electricity sale contract for difference of the power plant (dong/kWh).
b) Variable price used to calculate the price
ceiling is the estimated variable price for year N provided by the single
wholesaling Units for the electricity system and market operating Unit.
3. Price floor of thermoelectric sets
specified in Clause 3, Article 10 of this Circular.
4. The electricity system and market
operating Unit must announce the approved limit of price offering of
thermoelectric sets according to the electricity market operation schedule specified
in Annex 1 of this Circular.
Article 23.
Determining the market price ceiling
1. The electricity system and market
operating Unit shall calculate the plans of market price ceiling, including at
least 03 (three) plans.
2. The market price ceiling for year N is
determined by the principle:
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b) No greater than 115% of price ceiling of
highest quotation in thermoelectric sets with base load or intermediate load
with direct offered price in the electricity market;
Article 24. Choosing
the best new power plant
1. The best new power plant for year N
is the power plant participating in the electricity market and meeting the
following criteria:
a) Beginning commercial operation and
generating power with the whole installed capacity in year N-1;
b) Being power plant with base load,
classified by the criteria specified in Clause 3, Article 21 of this Circular;
c) Using
thermal
coal technology or combined cycle gas turbine technology;
d) Having the average cost of full electric
generation for 01 kWh as the lowest cost.
2. The single wholesaling Units shall make a
list of power plants which meet the criteria under Point a and c, Clause 1 of
this Article and provide data of electricity sale contract of such power plants
to the electricity system and market operating Unit to determine the best new
power plant. The data include:
a) Variable price for year N;
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c) Agreed power output for calculation of
contract price
3. Where there is no power plant meeting the
criteria specified under Point a, b and c, Clause 1 of this Article, the electricity
system and market operating Unit shall use the list of new plants chosen for
year N-1 and request the single wholesaling Units to update and re-provide
data specified in Clause 2 of this Article for calculating and choosing the
best new power plant for year N.
4. The electricity system and market
operating Unit shall calculate the average cost of full electric generation for
01 kWh for the power plants which have met the criteria specified under Point
a, b and c, Clause 1 of this Article by the following formula:
: Average cost of full electric generation
for 01 kWh in year N of the power plant (dong/kWh);
: Fixed price for year N under the
electricity sale contract for difference of the power plant(dong/kWh);
: Variable price for year N under the
electricity sale contract for difference of the power plant(dong/kWh);
: Agreed power output to calculate contract
price for year N of power plant (kWh);
: Estimated power output in year N of the
power plant determined from the electricity market simulation model by the
method of constrained scheduling (kWh).
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Article 25.
Principles to determine the market capacity price
1. Ensuring the best new power plant shall
recover adequate cost of electric generation upon participation in electricity
market.
2. Not applying the market capacity price for
night off-peak hours, in which the night off-peak hours are the hours from
00:00 AM to 04:00 AM and from 22:00 PM to 24:00 PM.
3. The market capacity price is proportional
to the forecast load of the national electricity system for transaction cycle.
Article 26. Order of
determining the market capacity price
The electricity system and market operating
Unit shall determine the market capacity in the following
order:
1. Determining the annual Deficient cost of
the best new power plant
a) Determining the Estimated revenue in the
market of the best new power plant in year N by the following formula:
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RTTĐ: Estimated revenue from the
market power price of the best new power plant in year N(dong);
i: Transaction cycle i in year N;
I: Total transaction cycles in year N;
SMPi: Estimated price of market
power of transaction cycle i in year N determined from the electricity market
simulation model by the method of unconstrained scheduling (dong/kWh);
: Estimated output at metering location of
the best new power plant at the transaction cycle i in year N determined from
the electricity market simulation model by the method of constrained scheduling
(kWh);
: .
b) Determinig the total annual cost of
electric generation of the best new power plant by the following formula:
In which:
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PBNE: Average cost of full
electric generation for 01 kWh of the best new power plant determined in Clause
4, Article 24 of this Circular (dong/kWh);
: Estimated output at the metering location
of the best new power plant at the transaction cycle i in year N determined
from the electricity market simulation model by the method of constrained
scheduling;
i: Transaction cycle i in year N;
I: Total transaction cycles in year N.
c) Annual Deficient cost of the best new
power plant determined by the following method:
In which:
AS: Deficient cost of the best new power
plant in year N (dong);
TCBNE: Total annual cost of
electric generation of the best new power plant in year N determined under
Point b of this Clause (dong);
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d) In case of calculing the annual Deficient
cost with negative value by the plan of lowest market price ceiling, the electricity
system and market operating Unit shall report to the Electricity Regulatory
Authority to choose the next best new power plant in the list of new power
plants specified in Article 24 of this Circular and re-calculate or review the
list of power plants participating in the electricity market to determine the
price ceiling rationally.
2. Determining the monthly Deficient cost
Deficient cost of the best new power plant is
determined by allocating the yearly Deficient cost into the month in year N by
the following formula:
In which:
t: Month t in year N;
MS: Deficient cost of month t of the best new
power plant (dong);
AS: Yearly Deficient cost of the best new
power plant in year N (dong);
: Peak load capacity in month t (MW).
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a) Determining the average available capacity
in a year of the best new power plant by the following formula:
In which:
QBNE: Average available capacity
in year N of the best new power plant (kW);
I: Total transaction cycles in year N, except
for night off-peak hours;
i: Transaction cycle in which the best new
power plant is estimated to be mobilized, except for night off-peak hours;
: Estimated mobilized capacity of the best
new power plant in transaction cycle i of year N as per the electricity market
simulation model by the method of constrained scheduling converted to the
metering location (kW).
b) Determing the market capacity price for
each transaction cycle in the next year by the following formula:
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I: Total transaction cycles in month t,
except for night off-peak hours;
i: Transaction cycle i in month t, except for
night off-peak hours;
: Price of market capacity of transaction
cycle i (dong/kW);
QBNE: Average available capacity
in year N of the best new power plant (kW);
MS: Deficient cost of month t of the best new
power plant (dong);
: Load of forecasting system of transaction
cycle i as per the load chart of forecastin typical day of month t is specified
in Article 19 of this Circular (MW);
: Minimum load of forecasting system for
month t (MW).
Article 27.
Determining the total yearly contract output
The total yearly contract output of the power
plant is determined by the following steps:
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2. Calculating the total yearly planned
output of the power plant by the following formula:
if 
if 
if 
In which:
: Total planned output of year N of the power
plant (kWh);
: Estimated output of year N of the power plant
determined from the plan for operation of electric system for the next year
converted to the metering location (kWh);
GO: Average power output generated in many
years of the power plant specified in the electricity sale contract (kWh);
a, b: Adjustment coefficient of yearly output is
determined according to the Regulation on method for price preparation, order
and procedures for verification of electricity sale contract which the Ministry
of Industry and Trade has issued.
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In which:
Qc: Total contract output of year
N (kWh);
: Planned output of year N of the power plant
(kWh);
: Output percentage paid at contract price
applicable to year N (%). This output percentage is specified in Clause 5 of
this Circular.
Article 28.
Determining monthly contract output
The monthly contract output of thermal power
plant and hydroelectric plant having reservoir with regulation capability of
more than 01 week is determined during the the operational planning of
electricity market for next year, including the following steps:
1. Using the electricity market simulation
model specified in Clause 2, Article 17 of this Circular by the method of
constrained scheduling to determine the estimated output of each month of power
plant.
2. Determining the monthly contract output by
the following formula:
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In which:
: Contract output of month t of power plant (kWh);
Qc: Total yearly output of power
plant (kWh);
: Estimated output in month t of power plant
determined from the electricity market simulation model by the method of
constrained scheduling (kWh).
Article 29.
Responsibility to determine and sign the output of yearly and monthly contract
1. The electricity system and market operating
Unit is responsible for:
a) Calculating the output of yearly and
monthly contract of the electricity generating Units as stipulated in Article
27 and 28 of this Circular;
b) Sending the calculation result of yearly
and monthly contract to the single wholesaling Units and the electricity
generating Units directly doing transaction for verification bedore 15 November
of each year.
2. The single wholesaling Units are
responsible for:
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b) Verifying and coordinating with the electricity
system and market operating Unit to handle the discrepancies in the calculation
result of yearly and monthly contract;
c) Supplementing appendix and amendments of
contract appendix on output of yearly and monthly contract into the electricity
sale contract for difference as per the calculation result.
3. The electricity generating Units directly
doing transaction are responsible for:
a) Providing data for the electricity system
and market operating Unit and the single wholesaling Units to calculate the
output of yearly and monthly contract;
b) Verifying and coordinating with the electricity
system and market operating Unit to handle the discrepancies in the calculation
result of yearly and monthly contract;
c) Supplementing appendix and amendments of
contract appendix on output of yearly and monthly contract into the electricity
sale contract for difference as per the calculation result.
Article 30. Determining
the estimated average electrical generation price for year N
1. The electricity system and market
operating Unit shall calculate the estimated average electrical generation
price for year N and the extent of change of estimated average electrical
generation price compared with year N-1.
2. The yearly average electrical generation
price for year N:
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In which:
j: Power plant j of the single electricity
generating Units directly doing transaction;
J: Total power plants of electricity
generating Units directly doing transaction;
PPDTB: Average electrical
generation price of the entire system (dong/kWh);
: Average full market price of year N
specified in Clause 4 of this Article (dong/kWh);
: Total power output in year N of the entire
system (kWh);
: Total power output in year N of the
electricity generating Units directly doing transaction (kWh);
: Total power output in the electricity sale
contract for difference in year N of the power plant j (kWh);
: Price of electricity sale contract for
difference in year N of power plant j (kWh);
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: Total cost of power purchase from the
multi-objective strategic hydropower plants (dong);
CDVPT: Total cost of auxiliary
services in year N (dong).
3. The electricity system and market
operating Unit shall gather information on the costs of BOT power plants, the
multi-objective strategic hydropower plants and the power plants providing the
auxiliary services from the Vietnam Electricty to calculate the yearly average
electrical generation price as stipulated in Clause 2 of this Article.
4. The average full market price is
determined by the following formular:
In which:
i: Transaction cycle i in year N;
I: Total transaction cycle in year N;
: Average full market price of year N (dong/kWh);
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: Estimated price of market power of
transaction cycle i determined from the unconstrained electricity market
simulation model (dong/kWh);
: Price of market capacity of transaction
cycle i (dong/kW).
Article 31. Publicizing
the plan for operation of electricity market for next year
1. After the plan for operation of
electricity market for next year is approved under the provisions in Article 17
of this Circular, the electricity system and market operating Unit shall announce
on its website the information on the input data and the results of operational
plan of electricity market for next year to the members of electricity
market.
2. The information on the plan for operation
of electricity market for next year is announced, including:
a) - Giá điện năng thị trường dự kiến
Estimated market power price;
- Result of selection of best new power plant;
- Hourly price of market capacity;
- Price ceiling of market power price;
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- Yearly contract output and output allocated
into months of power plants.
b) Input parameters for calculating the plan
for yearly operation of electricity market:
- Forecast load of the North, Central and
South and for the entire national electricity system;
- Hydroelectrical data of reservoirs used for
calculating and simulating the electricity market;
- Progress to put new power plants into
operation;
- Technical parameters about transmission
grid;
- Chart of estimated electricity import and
export;
- Yearly maintenance and repair schedule of
power plants, transmission grid and major gas supply sources.
3. The information on the plan for operation
of electricity market for next year is only provided for the electricity
generating units directly doing transaction owning the power plants directly
related to such information, including :
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b) Water value of hydropower plant;
c) Data about variable price of thermal power
plant are used in simulation calculation.
Section 2:
OPERATIONAL PLAN FOR NEXT MONTH
Article 32. Forecast
load for operational plan for next month
The electricity system and market operating
Unit shall forecast the load for operational plan for next month by the method
specified in Regulation on power transmission system issued by the Ministry of
Industry and Trade. The data of forecast load for operation plan for next month
include:
1. The total demand for load of national
electricity system and load of the North, Central and South for the entire year
and each week in a month.
2. The load chart of typical days of the
North, Central and South and the whole of national electricity system of weeks
in a month.
Article 33.
Calculating water value
The electricity system and market operating
Unit shall calculate the water value for weeks in next month. The result of
calculation of water value shall be used for operational plan for next month,
including
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2. Water value of hydropower plant in the
groups of ladder hydropower plants.
3. Water value of hydropower plants having
reservoir with regulation capability of more than 01 week.
4. Optial water level of each week in a month
of hydropower plants having reservoir with regulation capability of more than
01 week.
Article 34.
Classifying the generating set with base, intermediate and peak load
1. The electricity system and market
operating Unit shall classify generating set with base, intermediate and peak
load in next month according to the Procedures for classifying the generating
set and calculate the price ceiling of monthly quotation of thermoelectric
power plants issued by the Electricity Regulatory Authority.
2. The electricity system and market
operating Unit shall use the market simulation model to determine the monthly
average load factor of generating sets in next month.
3. Based on the monthly average load factor
from the simulation result, the generating sets are classified into following
03 (three) groups:
a) Group of generating sets with base load
includes the generating Units with average load factor greater or equal to 70%;
b) Group of generating sets with intermediate
load includes the generating Units with average load factor greater than 25%
and less than 70%;
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Article 35. Adjusting
the price ceiling of quotation of thermolelectric set
1. The electricity system and market
operating Unit shall calculate and adjust the price ceiling of quotation of
thermolelectric sets in next month by the method specified in d 22 of this
Circular base on:
a) Fuel price of next month in case the price
ceiling of quotation is specified in Clause 1, Article 22 of this Circular.
The fuel price of next month is the fuel
price announced by the competent authorities and applied for next month. In
case there is data of fuel price announced by the competent authorities, the
fuel price of next month is the one as per the payment documents of the last
month before the time to set up the plan for next month. The single wholesaling
Units shall update information on fuel price of thermal power plants in next
month and provide it for the electricity system and market operating Unit and
notify the electricity generating Units.
b) The variable price of thermal power plants
in case the price ceiling of quotation is specified in Clause 2, Article 22 of
this Circular.
The single wholesaling Units shall update
the changes of variable price of thermal power plants and provide them for the electricity
system and market operating Unit;
c) The result of classification of
thermoelectric set for next month as stipulated in Article 34 of this Circular.
2. The electricity system and market
operating Unit shall announce the price ceiling of quotation of thermoelectric
set in next month according to the electricity market operation schedule specified
in Annex 1 of this Circular.
Article 36. Adjusting
the monthly contract output
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In case the plant whose maintenance and
repair schedule is changed in months at the end of year, the Qc output
corresponding to the repair time of this month to the following year.
2. Where the actual hydrological situation of
hydropower plant is so different compared with the hydrological forecast
applied in calculating and planning the yearly operation, the power plants
shall coordinate and make confirmation with the electricity system and market
operating Unit and the single wholesaling Units and make report to the Electricity
Regulatory Authority for review and adjustment for next month.
Article 37.
Determining the hourly contract output
The electricity system and market operating
Unit shall determine the hourly contract output in next month for the power
plant as per the following steps:
1. Using the market simulation model as
stipulated in Clause 2, Article 17 of this Circular to determine the estimated
hourly output in a month of the power plant by the method of constrained
scheduling
2. Determining the hourly contract output by
the following formula:
In which:
i: ith transaction cycle in a
month;
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: Contract output of power plant in
transaction cycle i(kWh);
: Output with estimated generation of power
plant in transaction cycle i determined from the electricity market simulation
model by the method of constrained scheduling (kWh). ;
: Monthly contract output of the power plant
is determined under the provisions of Article 28 of this Circular (kWh).
3. Where the contract output of the power
plant in transaction cycle i is greater than the greatest generated output of
the power plant, the contract output in such transaction cycle shall be
adjusted by the greatest generated output of the power plant.
4. Where the contract output of thermal power
plant in transaction cycle i is greater than 0 MW and less than the lowest
stable generated capacity (Pmin) of the power plant, the contract output in
such transaction cycle shall be adjusted by the lowest stable generated
capacity of the power plant. The lowest stable generated capacity (Pmin) of the
power plant is determined by the lowest stable generated capacity of 01 (one)
generating set of the power plant with mobilized scheduling in the electricity
market simulation model of such cycle.
Where the contract output of hydropower
plants is less than the lowest stable generated capacity, it can be adjusted by
0 MW or equal to the lowest stable generated capacity.
5. The electricity system and market
operating Unit shall allocate the differential total output due to the
adjustment of hourly contract output under the provisions in Clause 3 and 4 of
this Article at other hours in a month on the principle of ensuring the monthly
contract output remains unchanged and complying with the provisions in the
Procedures for operational plan for next week, month and year which the
Electricity Regulatory Authority issues.
6. The electricity system and market
operating Unit shall send the result of calculation of hourly contract output
in a month to the single wholesaling Units and the electricity generating Units
directly doing transaction as per the electricity market operation schedule
specified in Annex 1 of this Circular.
7. The single wholesaling Units and the
electricity generating Units directly doing transaction shall sign for
confirmation of monthly contract output adjusted according to Article 36 of
this Circular and the hourly contract output as per the result of calculation
of the electricity system and market operating Unit.
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Article 38. Water
value for next week
1. The electricity system and market
operating Unit shall update the forecast load data, hydrological
data and relevant data to calculate the water value for next week.
2. The electricity system and market
operating Unit shall update information and re-calculate the water value for
next week and announce the following results:
a) Water value and hourly estimated output of
multi-objective strategic hydropower plants;
b) Water value of groups of ladder hydropower
plants and hydropower plants having reservoir with regulation capability of more
than 1 week;
c) Hourly estimated output of hydropower
plants having reservoir with regulation capability of less than 2 days;
d) Weekly limited water level of reservoirs with
regulation capability of more than 01 week under the provisions in the
Procedures for short and medium-term assessment of electricity system security issued
by the Electricity Regulatory Authority on the implementation of Regulation on
power transmission system issued by the Ministry of Industry and Trade.
Article 39.
Determining the contract output of hydropower plants having reservoir with
regulation capability from 02 to 01 week
1. The electricity system and market
operating Unit shall calculate and announce the weekly contract output and
allocate it to each transaction cycle in a week of the hydropower plants having
reservoir with regulation capability from 02 days to 01 week under the
provisions in the Procedures for operational plan for next week, month and year
which the Electricity Regulatory Authority issues.
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Article 40. Limit of
offered price of hydropower plant
1. The limit of offered price of hydropower
plant having reservoir with regulation capability of more than 01 week is
determined based on the water value for next week of such power plant is
announced under the provisions in Clause 2, Article 28 of this Circular,
specifically as follows:
a) Price floor of quotation is equal to 0
dong/kWh ;
b) Price ceiling of quotation is equal to the
highest value of:
- Water value of such power plant;
- Average price of price ceilings of
quotation of thermoelectric sets participating in the electricity market in the
monthly operational plan;
c) Every month, the electricity system and
market operating Unit shall announce the average price of the price ceilings of
quotation of thermoelectric sets for next month for hydropower plants having
the same schedule of announcing price ceiling of quotation of thermoelectric
sets in next month.
2. The limit of offered price of of thermal
power plant having reservoir with regulation capacity from 02 days to 01 week
is determined as follows:
a) Price floor of quotation is equal to 0
dong//kWh;
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- Highest water level of hydropower plants
participating in electricity market;
- Average price of price ceiling of quotation
of thermal power plants participating in electricity market;
c) Every week, the electricity system and
market operating Unit shall announce the highest water value of hydropower
plants participating in electricity market next week for the hydropower plants
having reservoir with regulation capability from 02 days to 01 week.
3. Where the reservoir of hydropower plant
violates the weekly limited water level, the price ceiling of quotation of such
hydropower plant is applied to the next week is equal to the variable cost of
the most expensive diesel oil-operated thermoelectric set in the electricity
system. When ensuring no violation of weekly limited water level, the plant
shall continue to apply the price ceiling under the provisions in Clause 1 or 2
of this Article from the Tuesday. Every month, the electricity system and
market operating Unit shall announce the price of the most expensive diesel
oil-operated thermoelectric set in the electricity system.
4. Where the hydropower plant is located in
the region with power backup lower than 5% announced according to the
Procedures for short and medium-term assessment of electricity system security
issued by the Electricity Regulatory Authority guiding the implementation of
Regulation on power transmission system issued by the Ministry of Industry and
Trade, the price ceiling of quotation of hydropower plants in this region of
assessment week is equal to the variable cost of the most expensive diesel
oil-operated thermoelectric set in the electricity system. When the power
backup of region is equal to or higher than 5% , the plants in such region
shall continue to apply the weekly price ceiling under the provisions in Clause
1 and 2 of this Article.
5. The hydropower plants participating in
electricity market shall offer price must meet the following requirements:
a) Complying the provisions on price ceiling
of quotation and price floor of quotation in Clause 1, 2, 3 and 4 of this
Article;
b) Constrained requirements on need of use of
downstream water and other hydrological constraints.
Chapter V
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Section: OPERATION OF
ELECTRICITY MARKET FOR NEXT DAY
Article 41.
Information for operation of electricity market for next day
Before 10:00 am of day D-1, The electricity
system and market operating Unit shall determine, calculate and announce the
following information:
1. Chart of load forecasting of day D of the
entire national electricity system and the North, Central and South.
2. Estimated output in each transaction cycle
of next day of multi-objective strategic hydropower plants, BOT power plants
and other power plants not directly offering price in the electricity market.
3. Total estimated gas output of next day of
gas thermal power plants using the same gas source.
4. Estimated imported and exported power
output in each transaction cycle of day D.
5. The results of assessment of short-term
system security for day D as per the provisions in the Regulation on power
transmission system issued by the Ministry of Industry and Trade.
6. Estimated output of hydropower plants
having reservoir with regulation capability of less than 02 days in each
transaction cycle of next day.
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Article 42. Price
quotation
1. The price quotation is specified in Annex
3 of this Circular and must comply with the following principles:
a) Having a maximum of 05 (five) pairs of
offered price (dong/kWh) and capacity (MW) for the set for each transaction
cycle of day D ;
b) Capacity in the price quotation is the
capacity at the terminal of generator;
c) Offered capacity of succeeding price band
must be lower than the capacity of preceding price band. The minimum offering step
is 03 (three) MW;
d) Having information on the technical
parameters of the set, including:
- The announced capacity of the set for day D;
- The lowest stable generated capacity of the
set;
- The speed of increase and decrease of
maxium capacity of the set;
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dd) The announced capacity of the set in the
quotation of day D is not lower than the announced capacity in day D-2 under
the Procedures for short and medium-term assessment of electricity system
security issued by the Electricity Regulatory Authority on the implementation
of Regulation on power transmission system issued by the Ministry of Industry
and Trade except for case of stop of set for unplanned repair (which must be
approved) or unforeseen technical incidents. The plant shall update the
announced capacity upon decrease in available capacity;
e) In normal condition, the first price
capacity band in the quotation of thermoelectric sets must be equal to the
lowest stable generated capacity of the set. The last price capacity band must
be equal to the announced capacity. For thermal power plants which may update
the hourly quotation with capacity lower than the lowest stable generated
capacity during the start and stop of set.
g) Hydropower plants may offer the first
capacity bands in each hour by 0 (zero) MW. For hydropower plants with regulation
capability over 02 days, the last price capacity band must be equal to the
announced capacity;
h) Unit of offered price is dong/kWh with the smallest decimal as 0.1;
i) Offered price is between the price floor
and price ceiling of the set and shall not decrease in the direction of
increase of offered capacity.
2. Modification of price quotation
a) The price offering Units may modify and
submit the price quotation for next day or for the remaining transaction cycles
in day D to the electricity system and market operating Unit at least 45
minutes before transaction cycle with modified price quotation;
b) The modified price quotation whose offered
price must not be changed compared with the price quotation for next day of
such price offering Units;
c) The modified price quotation whose
capacity must not be changed at capacity levels lower than or equal to the
announced capacity for next hour except in case of violation of technical
requirements of price quotation;
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dd) The electricity system and market
operating Unit shall check the validity of the modified price quotations and
use them as the scheduling price quotation for mobilization scheduling of next
hour and calculation of electricity market price.
Article 43. Price
offer of group of ladder hydropower plants
1. The group of ladder hydropower plants
shall offer price as per a price quotation for the whole group and comply with
the limit of offered price specified in Article 40 of this Circular.
2. The power plants in the group of ladder
hydropower plants shall agree and uniformly appoint the representative price
offering Units. Such Units shall submit the written registration together with
the written agreement between power plants in the group to the electricity
system and market operating Unit.
3. Where the representative price offering Unit
is not registered for the group of ladder hydropower plants, the electricity
system and market operating Unit shall announce the mobilization chart to the
plants of such group based on the result of calculation of water value of such
group.
4. The representative price offering Unit
must comply with regulations on price offering for all power plants in the
group of ladder hydropower plants.
5. Where the hydropower plant in the group of
ladder hydropower plants proposes self price offering, based on such proposal
and the optimal constraints of water use of the entire group, the Electricity
Regulatory Authority shall consider and decide the price offering of such
hydropower plant.
6. The water value of group of ladder
hydropower plants is the water value of the largest reservoir in such group.
The electricity system and market operating Unit shall determine the reservoir
used to calculate the water value for the group of ladder hydropower plants
together with classification of hydropower plants specified in Article 18 of
this Circular.
7. Where there is multi-objective strategic
hydropower plant in the group of ladder hydropower plants:
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b) When the announced output of
multi-objective strategic hydropower plant in the group is adjusted under the
provisions in Article 54 of this Circular, the electricity system and market
operating Unit must adjust the announced output of hydropower plants in the
lower ladder accordingly.
Article 44. Price
offer of other hydropower plants
1. The other hydropower plants having
reservoirs with regulation capability from 02 days or more make their price
offer in the market and comply with the limit of offered price specified in
Article 40 of this Circular.
2. The other hydropower plants having
reservoirs with regulation capability of less than 02 days must submit the
price quotation of day D to the electricity system and market operating Unit.
The quotation of such plants is specified as follows:
a) The offered price is 0 dong/kWh for all
price bands;
b) The offered capacity is equal to the
estimated generation capacity of generating set in the transaction cycle.
Article 45.
Submission of price quotation
1. Before 11:30 am of day D-1, the price
offering Units must submit the price quotation of day D.
2. The price offering Units shall submit
their price quotation through the market information system. In case of failure
to use the market information system due to incidents, the price offering price
shall reach an agreement with the electricity system and market operating Unit
on other modes for submission of price quotation in the priority order as
follows:
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b) By fax to the number specified by the
electricity system and market operating Unit;
c) Submitting the quotation directly at the
head office of the electricity system and market operating Unit.
Article 46. Checking
the validity of price quotation
1. Before 11:00 of day D-1, the electricity
system and market operating Unit shall check the validity of the price
quotation which it has received from the price offering Units under the
provisions of Article 42 of this Circular. Where the price offering Unit sends
many price quotations, only the last one shall be reviewed.
2. Where the price quotation is not valid,
the electricity system and market operating Unit shall inform the Units
submitting such price quotation and request such Units to re-submit the last
price quotation before the end time of price offering.
3. After receiving the notification from the
electricity system and market operating Unit of the invalid price quotation,
the price offering Units shall modify and re-submit the price quotation before
the end time of price offering.
Article 47. Scheduling
price quotation
1. After the end time of price offering, the
electricity system and market operating Unit shall check the validity of the
last price quotation it has received under the provisions in Article 42 of this
Circular. The last valid price quotation shall be used as the scheduling price
quotation for mobilization scheduling for next day.
2. Where the electricity system and market
operating Unit does not receive the price quotation or the last price quotation
of the price offering Unit is not valid, the electricity system and market
operating Unit shall use the default price quotation of such electricity
generating Units as the scheduling price quotation.
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a) For thermal power plants, the default
price quotation is the last valid price quotation. In case the last valid price
quotation is not consistent with the actual state of operation of the set, the
default price quotation is the one corresponding to the present state and fuel
used in the set of default price quotation applied to such month of the set.
The price offering Units shall prepare the set of default price quotation
applied to next month of the thermoelectric set corresponding to the state of
operation and fuel of the set and submit it to the electricity system and
market operating Unit before the 25th date of each month.
b) For the hydropower plants and group of
ladder hydropower plants, the default price quotation is the quotation with
offered price equal to the corresponding price ceiling of the hydropower plant
specifed in Article 40 of this Circular.
Article 48. Data used
for mobilization scheduling for next day
The electricity system and market operating
Unit must use the following data to set up the mobilization scheduling for next
day:
1. Daily load chart of the entire national
electricity system and each region of the North, Central and South
2. Scheduling price quotations of price
offering Units
3. Estimated output in each transaction cycle
of next day of power plants specified in Clause 2, Article 41, Clause 7,
Article 43 and Point b, Clause 2, Article 44 of this Circular.
4. Imported and exported power output
specified in Article 62 and 63 of this Circular.
5. Capacity of generating sets of power
plants providing the auxiliary services.
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7. Schedule of maintenance and repair of
transmission grid and generating sets which the electricity system and market
operating Unit has approved.
8. Testing schedule of generating set.
9. Mobilization chart of power plants whose
right to participate in the electricity market is suspended under the
provisions of Clause 3, Article 8 of this Circular.
10. The results of assessment of short-term
system security for day D under the provisions in the Regulation on power
transmission system issued by the Ministry of Industry and Trade.
11. Updated information
about the availability of the transmission grid and the generating sets from
the SCADA system or provided by the electricity transmitting Units or
electricity generating Units.
Article 49. Mobilization scheduling for next
day
The electricity system and market operating
Unit shall set up the mobilization scheduling for next day. The schedule for
next day includes:
1. Unconstrained mobilization schedule,
including:
a) Estimated price of market power in each
transaction cycle of next day;
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2. Constrained mobilization schedule,
including:
a) Estimated mobilization chart of each set
in each transaction cycle of next day, marginal price of each region in each
transaction cycle of next day.
b) Estimated schedule of stop, start and
state of grid connection of each set in next day;
c) Estimated mode of operation and wiring
diagram of electricity system in each transaction cycle of next day.
d) Warning information (if any).
3. Setup of mobilization schedule in case of
excessive capacity
The electricity system and market operating
Unit shall calculate the reduction in capacity towards the lowest stable
generated capacity or stop and change of restarting time of generating sets in
case of excessive capacity under the following principles:
a) Reduction in capacity of generating sets
with price of electricity sale contract in the order from high to low;
b) Stop of generating sets with price of
electricity sale contract (Pc) in the order from high to low;
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d) Upon restart in the order of generating sets
having price of electricity sale contract (Pc) in the order from low to high;
dd) Calculation of stopping time of
generating sets to meet the requirements of the system and limit of up and down
operation of generating sets with multi times.
Article 50.
Announcement of mobilization schedule for next day
Before 16:00 pm everyday, the electricity
system and market operating Unit shall announce information in mobilization
schedule for next day, specifically as follows:
1. Estimated mobilization capacity includes
the spinning backup capacity and frequency modulation of generating sets in each
transaction cycle of next day. The marginal price of each region in each
transaction cycle of next day.
2. Estimated market power price for each
transaction cycle of next day.
3. List of generating sets expected to
increasingly or decreasingly generate capacity in each transaction cycle of
next day.
4. Information on warning of shortage of
capacity in next day (if any), including:
a) Estimated transaction cycles with shortage
of capacity;
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c) Violation of constraints of system
security
5. Information on warning of excessive
capacity (if any) in next day, including:
a) Estimated transaction cycles with
excessive capacity;
b) Generating sets whose electricity
generation is expected to be stopped.
Article 51. Grid
connection of generating set
1. For slowly-started generating set, the
electricity generating Units shall prepare everything for grid connection of
such generating set as per the mobilization schedule for next day which the electricity
system and market operating Unit has announced. Where the start time of
generating set is greater than 24 hours, the electricity generating Units shall
connect the grid of such generating set based on the results of assessment of
short-term system security which the electricity system and market operating
Unit has announced.
2. For the generating set without slow start,
the electricity generating Units shall prepare everything for grid connection
of such generating set as per the mobilization schedule for next day which the electricity
system and market operating Unit has announced.
3. During the grid connection of
thermoelectric sets, the electricity generating Units shall update the hourly
capacity into the hourly quotation 60 minutes in advance before transaction
cycle for the operation and calculation of payment.
Article 52. Handling
in case of warning of capacity shortage
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2. The electricity system and market
operating Unit shall use the quotation of increased capacity as the scheduling
quotation for mobilization scheduling for next hour and calculation of
electricity market price.
Section 2: OPERATION
OF ELECTRICITY MARKET FOR NEXT HOUR
Article 53. Data of
mobilization scheduling for next hour
The electricity system and market operating
Unit shall use the following data for mobilization scheduling for next hour
1. The load chart of entire national
electricity system and the North, Central and South forecasting the next 3
hours and 03 following hours.
2. The grid connection plan of slowly-started
generating sets as per the announced mobilization schedule for next day.
3. The scheduling quotations of the price
offering Units with updating of hourly quotation of slowly-started generating
sets during grid connection, hourly quotation of generating sets during the
stop of generating set due to incident or reduced capacity due to unforeseen
technical incident, the hourly quotation of generating sets announcing the
increased capacity in case of current source shortage of electricity system.
The Units may update the hourly quotation at least 45 minutes prior to
transaction cycle.
4. Announced output of multi-objective
strategic hydropower plant.
5. Spinning backup capacity and frequency
modulation, quick start backup, cod backup and operation to be generated due to
the constrained security of electricity system for next hour.
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7. Other constraints of system security.
8. Testing schedule of generating set.
9. Capacity announced as per the mobilization
schedule for next day of power plants which do not offer price directly in the
electricity market.
10. Imported power output .
Article 54.
Adjustment of announced output of multi-objective strategic hydropower plant
1. Before mobilization scheduling for next
hour, the electricity system and market operating Unit may adjust the hourly
output of the multi-objective strategic hydropower plant announced under the
provisions in Clause 2, Article 41 of this Circular in the following cases:
a) Unexpected changes in hydrology;
b) Warning of capacity shortage as per the
mobilization schedule for next day;
c) Decision of competent state authorities on
regulation of reservoir of multi-objective strategic hydropower plant for the
purpose of flood control and irrigation.
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Article 55.
Mobilization scheduling for next hour
1. The electricity system and market
operating Unit shall set up the mobilization schedule for next hour for
generating sets by the method of constrained and unconstrained scheduling.
2. Mobilization scheduling for next hour in
case of capacity shortage
a) The electricity system and market
operating Unit sets up the mobilization schedule of generating sets in the
order as follows:
- As per the scheduling price quotation;
- Multi-objective strategic hydropower plants
as per the adjusted capacity;
- Generating sets providing the quick and
cold start backup services as per the mobilization schedule for next day;
- Generating sets providing the generation
operation services due to the constrained security of electricity system;
- Spinning backup capacity;
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b) The electricity system and market
operating Unit shall check and determine the expected capacity shedding to
ensure the system security.
3. Mobilization scheduling for next hour in
case of excessive capacity
The electricity system and market operating
Unit shall adjust the mobilization scheduling for next hour through the methods
in the order as follows
a) Stopping the generating sets voluntarily
stopping their electrical generation;
b) Gradually reducing the generated capacity
of slowly-started generating sets to the lowest stable generated capacity;
c) Reducing to a minimum of generated
capacity of generating set providing the spinning backup services;
d) Reducing to a minimum of generated
capacity of generating set providing the frequency modulation services ;
dd) Stopping the slowly-started generating
sets in the order as follow:
- Having the shortes start time;
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- Having start cost from low to high. The
start cost shall be negotiated by the single wholesaling Units with the electricity
system and market operating Unit.
- Having the lowest capacity level
sufficiently to deal with the excessive capacity.
Article 56.
Announcement of mobilization schedule for next hour
The electricity system and market operating
Unit shall announce the mobilization schedule for next hour 15 minutes prior to
the transaction cycle, including the following contents:
1. Forecast load for next hour of the entire
national electricity system and in the North, Central and South.
2. Mobilization schedule of generating sets,
marginal cost in the North, Central and South in next hour and 03 consecutive
hours scheduled under the provisions in Article 55 of this Circular.
3. Handling measures of the electricity
system and market operating Unit in case of capacity excess or shortage.
4. Information about adjustment of announced
capacity of multi-objective strategic hydropower plants under the provisions in
Article 54 of this Circular.
5. Estimated schedule of load shedding (if
any).
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Article 57.
Dispatching real time electricity system
1. The electricity system and market
operating Unit shall operate the electricity system in real time based on the
announced mobilization schedule for next hour and comply with the provisions on
operation of real time electricity system in the Regulation on power
transmission system issued by the Ministry of Industry and Trade.
2. The electricity generating Units must
comply with the dispatching order of the electricity system and market
operating Unit.
3. The electricity generating Units owning
the hydropower plants must comply with the provisions on weekly limited water
level specified in Article 38 of this Circular.
Article 58. Handling
in case of violation of weekly limited water level of hydropower plants
1. The electricity system and market
operating Unit shall warn of violation of weekly limited water level of plants.
The plants must adjust the offered price in the next days to ensure no further
violation of weekly limited water level.
2. Where the reservoir of power plant commits
the weekly limited water level for 02 consecutive weeks, from 12:00 pm of
Monday of the next week, the quotation of such power plant shall not be used
for mobilization scheduling. The electricity system and market operating Unit
shall intervene in the mobilization schedule of such power plants based on the
result of calculation of water value to ensure the requirements on security of
electricity system and bring the water level of reservoir to the weekly limited
water level.
Where the water level of reservoir is
completely violated due to the mobilization on the basis of price quotation of
the power plant, not due to mobilization to ensure the requirements on security
of electricity system, within the time of being intervened, such plants shall
be paid by 90% of the price of electricity sale contract but not exceeding 02
weeks from the time of intervention.
Where the water level of reservoir is
violated due to mobilization to ensure the security of electricity system, such
plants are paid at the price of electricity sale contract during the time of
intervention.
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4. When ensuring no violation of weekly
limited water level, the hydropower plant may continue its participation in the
price offering in the next week.
5. Before 10:00 am of Mondays, the electricity
system and market operating Unit must announce the mobilization scheduling from
Tuesdays to the electricity generating Units and the single wholesaling Units in
the following cases:
a) The power plants violates its water level
of reservoir and the power plants whose mobilization schedule is intervened;
b) The water level of power plant is back to
the weekly limited water level and such power plant may offer its price again.
6. Before 10:00 am of day D-1, based on the
hydrological condition and water level of reservoir of such hydropower plant,
the electricity system and market operating Unit shall calculate and announce
the output expected to be mobilized hourly in next day of power plant with
intervention in mobilization schedule on the following principles:
a) Ensuring the security of power supply and
constraints on requirement for downstream water use and other technical constraints.
b) Ensuring the minimization of power
purchase costs for the entire system.
Article 59.
Intervention in electricity system
1. The electricity system and market
operating Unit may intervene in the electricity market in the following cases:
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b) Failing to present the mobilization
schedule for next hour 15 minutes prior to operational time.
2. In case of intervention in electricity
market, the electricity system and market operating Unit shall mobilize the
generating sets to ensure the objectives in the order as follows:
a) Ensuring the balance of generated capacity
and load;
b) Meeting the requirements on frequency
modulation backup;
c) Meeting the requirements on spinning
backup;
d) Meeting the requirements on voltage
quality;
3. Announcing information on electricity
market
a) When intervening in the electricity
market, the electricity system and market operating Unit must announce the
following contents:
- The reasons for intervention in electricity
market;
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b) Within 24 hours after after the end of
intervention in electricity market, the electricity system and market operating
Unit shall announce the following contents:
- The reasons for intervention in the
electricity market;
- The transaction cycles with intervention in
the electricity market;
- The measures which the electricity system
and market operating Unit applies for intervention in the electricity market;
Article 60. Stop of
electricity market
1. The electricity market stop operation upon
occurrence of one of the following cases:
a) Due to disaster emergency situations or
protection of national security;
b) The electricity system and market
operating Unit requires the stop of electricity market in one of the following
cases:
- The electricity system is operating in an
extreme emergency mode specified in the Regulation on power transmission system
issued by the Ministry of Industry and Trade.
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c) Other cases as required by the competent
authorities.
2. The Electricity Regulatory Authority shall
consider and decide the stop of electricity market in cases specified under
Point a and b, Clause 1 of this Article and notify the electricity system and
market operating Unit.
3. The electricity system and market
operating Unit shall inform the participants of electricity market of the
decision on stopping the electricity market of the Electricity Regulatory
Authority.
4. Operation of electricity system during the
time of stopping the electricity market
a) The electricity system and market
operating Unit must dispatch and operate the electricity system by the
following principles:
- Ensuring the system operates safely, stably
and reliably with the lowest cost of power purchase for the entire system;
- Ensuring the implementation of agreements
on output in electricity import and export contracts and electricity sale
contracts of BOT power plants and electricity sale contracts with output
commitment of other power plants;
b) The electricity generating Units, electricity
transmitting Units and other relevant Units must comply with the dispatching
order of the electricity system and market operating Unit.
Article 61.
Restoration of electricity market
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a) The causes leadin to the stop of
electricity market have been remedied;
b) The electricity system and market
operating Unit has confirmed the capability of re-operation of electricity
market.
2. The Electricity Regulatory Authority shall
consider and decide the restoration of electricity market and inform the electricity
system and market operating Unit.
3. The electricity system and market
operating Unit shall inform the participants of electricity market of decision
on restoration of electricity market of the Electricity Regulatory Authority.
Section 4:
ELECTRICITY IMPORT AND EXPORT IN OPERATION OF ELECTRICITY MARKET
Article 62. Handling
of exported power in mobilization schedule
1. Before 10:00 am of day D-1, the electricity
system and market operating Unit shall announce the estimated exported power
output in each transaction cycle of day D.
2. The exported power output is calculated as
load at the export point and is used to calculate the forecast load of system
for mobilization scheduling of next days and hours.
Article 63. Handling
of imported power in mobilization scheduling
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2. The imported power output in mobilization
scheduling is calculated as the source to be generated with the chart announced
in advance in next day.
Article 64. Payment
for imported and exported power
The imported power is paid under the
electricity sale contract signed between the parties.
Chapter VI
CALCULATION
OF PRICE OF MARKET POWER AND PAYMENT IN ELECTRICITY MARKET
Section 1: POWER
METERING DATA
Article 65. Supply of
metering data
1. Before 15:00 pm of day D+1, the power
metering data managing Units shall provide the electricity system and market
operating Unit and the single wholesaling Units with the power metering data
of each transaction cycle of day D.
2. Before the eighth working day after the
end of payment cycle, the power metering data managing Units shall provide the electricity
system and market operating Unit with the power metering data in the payment
cycle specified in Regulation on power metering in the competitive electricity
generation market issued by the Ministry of Industry and Trade.
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The electricity system and market operating
Unit shall store the power metering data and relevant dossiers for a period of
at least 05 years.
Section 2:
CALCULATION OF POWER PRICE OF MARKET POWER
Article 67.
Determining the price of market electricity
1. After transaction day D, the electricity
system and market operating Unit shall set up the market electricity price
calculation schedule for each transaction cycle of day D in the order as
follows:
a) Calculating the system load in transaction
cycle by converting the metering output to the terminal of generating sets;
b) Setting the market electricity price
calculation schedule by the method of unconstrained scheduling in the order as
follows:
- Making the fixed arrangement under the base
of load chart of electricity system the output actually generated of
electricity generating Units indirectly doing transactions of electricity
market, imported power, BOT power plants, tested generating sets, power plants
in industrial parks selling only part of output into the national electricity
system and generating sets separated from electricity market;
- Arranging capacity bands in the scheduling
price quotation of the electricity generating Units directly doing
transactions.
2. The price of market power is equal to the
offered price of the last capacity band scheduled to meet the system load in
the market electricity price calculation schedule. In case the offered price of
the last capacity band in the price calculation schedule of market power is
higher than the market price ceiling, the price of market power is calculated
by the market price ceiling.
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Article 68.
Determining the paid capacity
1. The principles to determine the paid
capacity for each transaction cycle:
a) The generating sets participating in
electricity generation in each cycle in the market are scheduled to receive the
price of market capacity for such cycle except the slowly-started generating
sets stopped for backup or due to breakdown;
b) The paid capacity of generating set is at
least equal to the power output of such generating set at the metering location;
c) Where the total capacity of generating
sets with equal offered price, the capacity receiving the price of market
capacity at such price band is evenly divided to the generating sets.
2. After transaction day D, the electricity
system and market operating Unit shall set the capacity schedule for each
transaction cycle of day Article in the order as follows:
a) Calculating the adjusted load in transaction
cycle is the system load plus the following components:
- Spinning backup capacity for transaction
cycle;
- Frequency modulation capacity for
transaction cycle;
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b) Implementation of capacity scheduling by
the method of unconstrained scheduling to meet the adjusted load determined
under Point a of this Clause in the order as follows:
- Making the fixed arrangement under the base
of load chart of electricity system the output actually generated of
electricity generating Units indirectly doing transactions of electricity
market, imported power, BOT power plants, tested generating sets, power plants
in industrial parks selling only part of output into the national electricity
system and generating sets separated from electricity market;
- Making the fixed arrangement under the base
of load chart of electricity system the frequency modulation capacity, spinning
backup and increasingly generated capacity of generating sets;
- Making arrangement of capacity bands in the
scheduling price quotation of electricity generating Units except for
slowly-started generating sets which have stopped their operation for backup or
stopped due to breakdown.
3. Amount of paid capacity of generating set
in transaction cycle is calculated by the amount of capacity of such generating
set arranged in the capacity schedule.
4. Before 9:00 am of day D+2, the electricity
system and market operating Unit shall announce the amount of paid capacity of
each generating set in transaction cycles of day D.
Article 69.
Determining the price of market power and paid capacity upon intervention in
electricity market
1. In case the market intervention time is
less than 24 hours:
a) The electricity system and market
operating Unit shall use the valid price quotation to determine the price of
market power specified in Article 67 and the paid capacity specified in Article
58 of this Circular;
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2. Where the market intervention time is
greater or equal to 24 hours, the electricity system and market operating Unit
shall not calculate the price of market power and the paid capacity for the
period of market intervention.
Section 3: MAKING
PAYMENT TO THE ELECTRICITY GENERATING UNITS DIRECTLY DOING TRANSACTION
Article 70. Power
output for payment in electricity market
1. The electricity system and market
operating Unit shall calculate the components of power output of the power
plant in the transaction cycle for payment in electricity market, including:
a) Output of power paid at the offered price
for thermal power plants having their offered price higher than the market
price ceiling (Qbp);
b) Power output increasingly generated
(Qcon);
c) Power output generated for difference compared
with the output mobilized by the dispatching order (Qdu);
d) Output of power payment at the price of
market power (Qsmp).
2. The power output generated for difference compared
with the output mobilized by the dispatching order (Qdu) of the power plant in
transaction cycle is determined in the order as follows:
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The output mobilized by the dispatching order
is the output at the terminal of generator is calculated based on the
dispatching order of mobilized generating set of the electricity system and
market operating Unit and based on the capacity by the dispatching order and
the speed of load increasing and reduction of the generating set. The output
mobilized by the dispatching order is determined by the following formular:
In which:
i: ith transaction cycle;
J: Number of times of changed dispatching
order in transaction cycle i;
: jth moment in transaction cycle
i when the electricity system and market operating Unit has its dispatching
order for change of capacity of the generating set (minute);
: Moment when the generating set reaches the
capacity level of which the electricity system and market operating Unit issues
the dispatching order at the moment
(minute);
: Output mobilized by the dispatching order
at the terminal of generator determined for transaction cycle i;
: Capacity dispatched by the electricity
system and market operating Unit for the generating set at the moment
;
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The period from the moment of dispatching
order capacity 
to the moment 
when the generating set
reaches capacity 
is
determined as follows:
In which:
a: Speed of load increasing and reduction of
the generating set registered in the scheduling price quotation (MW/minute).
The speed of load increasing and reduction of
the generating set registered in the scheduling price quotation must be
consistent with the speed of load increasing and reduction announced in the
electricity sale contract. In case the electricity sale contracts do not have
the speed of load increasing and reduction or the speed of load increasing and
reduction in the contract has difference compared with reality. The electricity
generating Units shall determine such data according to the testing result or
aggregation from the operational reality of the generating set and sign the
contract annex on such technical features with the single wholesaling Units as
a basis for payment;
b) The electricity system and market
operating Unit shall calculate and convert the output mobilized by dispatching
order (Qddi j ) to the metering location;
c) Power output generated for difference compared
with the output mobilized by the dispatching order is determined by the
following formula:
In which:
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: Metered power output of the power plant in
transaction cycle i (kWh);
: Output mobilized by dispatching order
converted to the metering location for transaction cycle i.
d) In case of start or stop of thermoelectric
set (not due to breakdown), such output Qdu is equal to 0 (Qdui = 0). If such
generating set is technically constrained and affect the generated capacity of
other generating sets of the plant, such affected generating sets whose output
Qdu shall not be counted (Qdui = 0).
dd) In order to increase the accuracy in
determining the component Qdu, the meters at terminal of generating set and the
meters installed at the self-used metering location of the generating set (if
any) are used with priority to determine the amount of actual generation at the
terminal of generating sets for comparison with the compliance with dispatching
order as per the management system of dispatching order (DIM);
e) The permissible dispatching power error
for generating sets with their installed capacity of less than 100 MW is 5% and
3 % for generating sets with their installed capacity from 100 MW or more but
not less than 1.5 MW in any case. In case the output 
is within the permissible error limit, such
output is equal to 0 (=
0).
3. Output of power paid at the offered price
for thermal power plant with the offered price greater than the market price
ceiling in transaction cycle determined as follows:
a) Determining the generating sets with the
offered price higher than the price ceiling scheduled to calculate the market
price for transaction cycle i and metering location of such generating set;
b) Calculating the output of power paid at
the offered price at each metering location determined at Point a of this
Clause by the following formular:
if 
and 
≥ 0
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if 
In which:
i: ith transaction cycle;
j: jth metering point of thermal
power plant, determined under Point a of this Clause;
: Output of powet paid at the offered price
at metering location j in transaction cycle i (kWh);
: Metered power output at the metering
location j trong transaction cycle i (kWh);
: Output of power in proportion to the
capacity with the offered price lower than or equal to the market price ceiling
in transaction cycle i of generating sets connected to the metering location j
and converted to such metering location (kWh);
: Output of power in proportion to the
capacity with the offered price higher the market price ceiling and arranged in
the schedule of market price calculation in transaction cycle i of generating
sets connected to the metering location j and converted to such metering
location (kWh);
: Power output generated for difference compared
with the output mobilized by the dispatching order of generating sets connected
to the metering location j and converted to such metering location (kWh).
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In which:
j: jth metering point of thermal
power plant, determined under Point a of this Clause;
J: Total of metering points of power plant
having generating set with the offered price higher than the market price
ceiling and scheduled for calculation of market price;
: Output of power paid at the offered price
of power plant in transaction cycle i (kWh);
: Output of power paid at the offered price
at the metering location j in transaction cycle i (kWh).
4. Output of power increasingly generated of
the power plant in transaction cycle determined in the order as follows:
a) Calculating the power output increasingly
generated in transaction cycle at the terminal of generating set by the
following formular:
If Qdu > 0:
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If Qdu ≤ 0:
In which:
: Power out increasingly generated of
generating set counted at the terminal in transaction cycle i (kWh);
: Paid and metered output of generating set g
in transaction cycle i converted to the terminal of generating set (kWh);
i: ith transaction cycle;
J: Number of times of changed dispatching
order in transaction cycle i;
: jth moment in transaction cycle
i where the electricity system and market operating Unit issues the dispatching
order to change capacity of generating set due to constraint (minute). If at
this moment but the capacity of generating set is lower than
then is determined as the moment when the generating
set reaches the capacity ;
: Moment when the generating set reaches the
capacity dispatched by the electricity system and market operating Unit at the
moment (minute); If
at this moment but the capacity of generating set is lower than then is determined as the moment when the
generating set reaches the capacity ;
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: Capacity dispatched by the electricity
system and market operating Unit mo6ngthe generating set at the moment . If this capacity is less
than then such
capacity is calculated by ;
: Capacity reached by the generating set at
the moment ;
: Power output generated for difference compared
with the output mobilized by the dispatching order converted to the terminal of
generator (Qdu);
The period from the moment of dispatching
order capacity 
to the moment when the generating set
reaches the capacityis
determined as follows:
In which:
a: Speed of load increasing and reduction of
the generating set registered in the scheduling price quotation (MW/minute).
b) Determining the power output increasingly
generated in transaction cycle of the generating set, 
, by converting the output 
from the terminal of generating
set to the metering location. In case of start or stop of thermoelectric set
(not due to breakdown), then is equal to 0;
c) Calculation of power output increasingly
generated of the power plant in transaction cycle i by the following formula:
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In which:
: Total output increasingly generated of the
power plant in transaction cycle i (kWh) ;
g: Generating set with increased generation of
the power plant in transaction cycle i;
G: Total generating set with increased
generation of the power plant in transaction cycle i;
: Output increasingly generated of generating
set g in transaction cycle i (kWh).
5. The output of power paid at the price of
market power of the power plant in transaction cycle i is determined by the
following formula:
a) In case of power output generated for
difference compared with the output mobilized by dispatching order (> 0):
b) In case of power output generated for difference
compared with the output mobilized by the negative dispatching order (< 0):
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In which:
: Output of power paid at the price of market
power of the power plant in transaction cycle i (kWh);
: Metered power output of the power plant in
transaction cycle i (kWh);
: Power output is paid at the offered price
in transaction cycle i for thermal power plants having their offered price
higher than the market price ceiling (kWh);
: Power output increasingly generated of
power plant in transaction cycle i (kWh);
: Power output generated for difference compared
with the output mobilized by the dispatching order in transaction cycle i.
Article 71. Adjusting
the power output for payment in electricity market
1. The components of power output for payment
in the market is adjusted in the following cases:
a) If in transition cycle i, the metered
power output of the power plant is less than or equal to the hourly contract
power output (≤ );
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2. The electricity system and market
operating Unit shall calculate and re-adjust the components of power output for
payment in the market in transaction cycles specified in Clause 1, Article 68
of this Circular, based on the following output components:
a) The hourly contract power output of power
plant in transaction cycle i () is determined under the provisions in
Article 37 of this Circular;
b) The power output paid at the market power
price (Qsmpi) of the power plant in transaction cycle i is determined under the
provisions in Clause 5, Article 68 of this Circular;
c) Metered power output of power plant in
transition cycle i ().
3. Principles of adjustment
a) In the case specified under Point a, Clause 1
of this Article, the power output increasingly generated (Qconi) and the power
output paid at the offered price for the power plants having their offered
price higher than the market price ceiling (Qbpi) adjusted in such transaction
cycle is equal to 0 (Qconi = 0; Qbpi = 0);
b) In the case specified under Point b, Clause 1
of this Article, the power output for payment in electricity market is adjusted
on the principle of ensuring no change of metered power output in such
transaction cycle and under the provisions in the Procedures for scheduling and
mobilizing the generating sets, real-time operation and calculate the payment
in the electricity market which the Electricity Regulatory Authority has
issued.
Article 72. Payment
of market power
1. The electricity system and market
operating Unit shall calculate the total of payment of market power of power
plant in transaction cycle by the following method:
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In which:
Rg: Total payments of market power in the
payment cycle (dong);
Rsmp: Payment for output to be paid at the
price of market power in the payment cycle (dong);
Rbp: Payment for output to be paid at the
offered price for thermal power plants having their offered price higher than
the market price ceiling in the payment (dong);
: Payment for the power output increasingly
generated in the payment cycle (dong);
Rdu: Payment for the power out generated for
difference compared with the output mobilized by the the dispatching order in
payment cycle (dong).
2. The payment for the output to be paid at
the price of market power of power plant in transaction cycle determined in the
order as follows:
a) Calculation for each transaction cycle by
the following formula:
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: Payment for the output to be paid at the
price of market power of power plant of transaction cycle i in payment cycle
(dong);
SMPi : Price of market power of transaction
cycle i in the payment cycle (dong/kWh);
: Power out to be paid at the price of market
power of transaction cycle i in payment cycle (kWh)
b) Calculation of payment cycle by the
following method:
In which:
: Payment for the output to be paid at the
price of market power in the payment cycle (dong);
i: ith transaction cycle in the
payment cycle;
I: Total transaction cycles of payment cycle;
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3. The payment for the output to be paid at
the offered price for thermal power plants having their offered price higher
than the market price ceiling in payment cycle determined in the order as
follows:
a) Calculation for each transaction cycle by
the following method:
In which:
: Payment for power with higher offered price
than the price ceiling of power plant in transaction cycle i (dong);
j: jth price band in the quotation
of generating sets of thermal power plants having their offered price higher
than the market price ceiling and arranged in the schedule of market power
price calculation;
J: Total price bands in price quotation of
thermal power plants having their offered price higher than the market price
ceiling;
: Offered price corresponding to price band i
in quotation of generating sets of thermal power plant g in transaction cycle i
(dong/kWh);
: Highestoffered price in price bands
arranged in the schedule of market power price calculation of thermal power
plant in transaction cycle i (dong/kWh);
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: Total power output with offered price
higher than the market price ceiling of thermal power plant in transaction
cycle i (kWh).
b) Calculation for payment cycle by the
following formula:
In which:
: Payment for power offered at the price
higher than the price ceiling of power plant in payment cycle (dong);
i: Transaction cycle i in which the power
plants are mobilized with their offered price higher than the price ceiling;
I: Total transaction cycles in which the power
plants are mobilized with their offered price higher than the price ceiling;
: Payment for power offered at the price
higher than the price ceiling of power plant in transaction cycle i (dong).
4. The payment for the power output increasingly
generated of power plant in transaction cycle determined in the order as
following:
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In which:
: Payment for power output increasingly
generated in transaction cycle i (dong);
g: Generating set with increased generation
of power plant in transaction cycle i;
G: Total generating sets with increased
generation of power plant in transaction cycle i;
: Power increasingly generated of generating
set g in transaction cycle i (kWh);
: The highest offered price corresponding to
the capacity band increasingly generated of generating set g in transaction
cycle i (dong/kWh). For hydropower plants, if such offered price is higher than
the price ceiling of electricity market, the price ceiling of electricity
market shall be taken.
b) Calculation for payment cycle by the
following formula:
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Rcon: Payment for power output increasingly
generated in payment cycle (dong);
i: ith transaction cycle of
payment cycle in which the power plant must have additional power generation by
the dispatching order;
I: Total transaction cycles of payment cycle
in which the power plant must have additional power generation by the
dispatching order;
Rconi : Payment for power output increasingly
generated in transaction cycle i (dong).
5. Where the hydropower plants are mobilized
for generation due to constrained conditions with their offered price higher
than the market price ceiling or their capacity is mobilized with price band
higher than the market price ceiling, such plants shall be paid for the
corresponding generated output in that cycle at the market price ceiling.
6. The payment for power output generated for
difference compared with the output mobilized by the dispatching order of the
power plant in transaction cycle.
a) Calculation for each transaction cycle by
the following formula:
- In case of power output increasingly
generated compared with the dispatching order:
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: Payment for power output generated for
difference compared with the dispatching order in transaction cycle i (dong);
g: Generating set with increased generation
compared with the dispatching order of power plant in transaction cycle i;
G: Total generating sets with increased
generation compared with the dispatching order of power plant in transaction
cycle i;
: Power increasingly generated compared with
the dispatching order of generating set g in transaction cycle i (kWh);
: The lowest offered price of all generating
sets in transaction cycle i (dong/kWh)
- In case of power output decreasingly
generated compared with dispatching order:
In which:
: Payment for power output generated for
difference compared with dispatching order in transaction cycle i (dong);
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G: Total generating sets with decreasing
generation compared with the dispatching order of power plant in transaction
cycle i;
: Power decreasingly generated compared with
the dispatching order of generating set g in transaction cycle i (kWh);
SMPi : Price of market power in transaction
cycle i (dong/kWh);
Pbpi,max: Power price of the most expensive
generating set paid in transaction cycle i;
b) Calculation for payment cycle by the
following formula:
In which:
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i: ith transaction cycle of
payment cycle in which the thermal power plant has generated for difference
compared with dispatching order;
I: Total transaction cycle of payment cycle
in which the thermal power plant has generated for difference compared with
dispatching order;
: Payment for power output generated for
difference compared with the output mobilized by the dispatching order in
transaction cycle i (dong)..
Article 73. Payment
of market capacity
The electricity system and market operating
Unit shall calculate the payment of market power for the power plant in
transaction cycle in the order as follows:
1. Calculation for each transaction cycle by
the following formula:
In which:
: Capacity payment for power plant in
transaction cycle i (dong);
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G: Total generating sets of power plant paid
at the capacity price;
: Price of market capacity in transaction
cycle i (dong/kW);
: Amount of paid capacity of generating set g
in transaction cycle i converted to the metering location (kW).
2. Calculation for each transaction cycle by
the following formula:
In which:
Rcan: Capacity payment for power plant in
payment cycle (dong);
i: ith transaction cycle in
payment cycle;
I: Total transaction cycles in payment cycle;
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Article 74. Payment
under electricity sale contract for difference
Based on the price of market power and market
capacity which the electricity system and market operating Unit announces, the
electricity generating Units shall calculate the payment under the electricity
sale contract for difference in payment cycle in the order as follows:
Calculation for each transaction cycle by the
following formula:
In which:
: Payment for difference in transaction cycle
i (dong);
: Power output paid at contract price in
transaction cycle i (kWh);
Pc: Price of electricity sale
contract for difference (dong/kWh). For hydropower plants, such contract price
does not include the tax of water resources and forest environment fees;
SMPi: Price of market power in
transaction cycle i (dong/kWh);
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Calculation for each transaction cycle by the
following formula:
In which:
Rc: Other payment for difference in payment
cycle (dong);
i: ith transaction cycle of payment
cycle;
I: Total transaction cyles of payment cycle;
: Other payment for difference in transaction
cycle i (dong).
Article 75. Payment
upon intervention in electricity market
1. Where the time for market intervention is
less than 24 hours, the electricity generating Units shall receive the payments
specified in Article 72, 73 and 74 at the price of market power and the amount
of paid capacity specified in Article 69 of this Circular.
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Article 76. Payment upon stop of electricity
market
During stop of electricity market, the
electricity generating Units shall be paid at the contract price for all
metered power output.
Section 4: PAYMENT OF AUXILIARY SERVICES AND
OTHER PAYMENTS
Article 77. Payment
for spinning backup services and frequency modulation services
The electricity system and market operating
Unit shall calculate the payment to the electricity generating Units providing
the spinning backup services and frequency modulation services as stipulated by
the Ministry of Industry and Trade.
Article 78. Payment
for quick start backup services, cold backup services, generation operation
services due to the constrained security of electricity system, voltage
adjustment and black start services
The Units providing the quick start backup
services, cold backup services, generation operation services due to the
constrained security of electricity system, voltage adjustment and black start
services shall be paid under the auxiliary services supply contract in the form
issued by the Ministry of Industry and Trade.
Article 79. Payment
for hydropower plants having reservoir with regulation capability of less than
02 days
1. Calculating and paying revenues of each
transaction cycle for hydropower plants having reservoir with regulation
capability of less than 02 days by the following formula:
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In which:
Rgi: Payment for hydropower plants
having reservoir with regulation capability of less than 02 days in transaction
cycle i (dong);
Pc: Price of electricity sale contract (dong/kWh);
Qhci: Power output adjusted in
transaction cycle i (kWh) is determined as follows:
- If Qdui > 0, Qhci =
Qmi - Qdui;
- If Qdui ≤ 0, Qhci =
Qmi.
Qmi: Power output at the metering
location in transaction cycle i (kWh);
Qdui: Power output generated for
difference compared with the dispatching order (kWh) in transaction cycle i.
Rdui: Payment for power output
generated for difference compared with the the output mobilized by the
dispatching order in transaction cycle i (dong);
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CANi: Price of market capacity in
transaction cycle i (dong/kWh);
α: Percentage of power output paid at
contract price for hydropower plants having reservoirs with regulation
capability of less than 02 days.
The electricity generating Units shall
calculate the payment at the price of electricity sale contract (Pc × Qhci
× α). The electricity system and market operating Unit shall calculate the
remaining payments.
2. Payment made for payment cycle by the
following formula:
In which:
: Payment for plant having reservoir with
regulation capability of less than 02 days (dong);
i: ith transaction cycle of
payment cycle;
I: Total transaction cycles of payment cycle;
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Article 80. Other
payments
1. The electricity generating Units having
generating sets or receiving reactive capacity in the mode of synchronous
compensation running shall be paid for the active power amount receiving from
power grid under the provisions in electricity sale contract.
2. Where the monthly power metering output
provided by the power metering data managing Units under the provisions in
Clause 2, Article 65 has a difference compared with the total metered power of
days in month provided by the power metering data managing Units under the
provisions in Clause 1, Article 65 of this Circular. The difference of power
shall be paid at the price of electricity sale contract signed between the single
wholesaling Units and the electricity generating Units.
3. The thermoelectric sets are required to
stop operating as stipulated under Point dd, Clause 3, Article 55 of this
Circular or must stop 01 boiler to reduce capacity as stipulated under Point b,
Clause 3, Article 55 of this Circular shall be paid the start cost as agreed
between the single wholesaling Units and the electricity generating Units. The
electricity system and market operating Unit must confirm such events for
generating sets which the electricity generating Units as a basis for payment
of start cost for the single wholesaling Units .
4. Where the generating sets are constrained
to decrease their capacity due to violation of limit of thermal grid related to
direct transmission of capacity of power plant to the system but the cause is
not due to the fault of power plant leading to the failure to ensure their
hourly contract output, then the hourly contract output in contrained cycles
must be generated with reduced capacity applied to the payment in electricity
market of the plant adjusted by the output actually generated of the plant in
such transaction cycle. The electricity generating Units and the single
wholesaling Units shall modify and supplement the annex of monthly contract
output as a basis for payment. Where the generating sets must be re-started,
they shall be paid the start cost as agreed between the single wholesaling
Units and the electricity generating Units.
5. Where the generating sets are constrained
to decrease their capacity or stop operation for repair or maintenance of line
directly connected to power plant or the related lines leading to the power cut
of line directly connected to power plant leading to the failure to ensure the
hourly contract output, the hourly contract output in relevant cycles applied
for payment in electricity market of the power plant adjusted by the output
actually generated of the power plant in such transaction cycle. The
electricity generating Units and the single wholesaling Units shall modify or
supplement the annex of monthly contract output as a basis for payment. Where
the generating sets must be re-started, they shall be paid the start cost as
agreed between the single wholesaling Units and the electricity generating Units.
6. Where the power plants have the testing
generating sets, such power plants shall be separated from the electricity
market in the testing running cycles. The total generated output of power plant
to the grid in cycles with testing paid under the provisions in the electricity
sale contract signed with the single wholesaling Units corresponding to the
configuration of generating sets and type of fuel used.
7. Where the gas turbine power plants must
stop their operation and re-start as required by the electricity system and
market operating Unit for the reason of system security during the time the
available single cycle generating sets operate with mixed fuel or not main
fuel, such plants shall be paid the start cost as agreed between the
electricity generating Units and single wholesaling Units .
8. Where the gas turbine power plants sharing
the same heat recovery steam have the moment of operation of single cycle,
operation with mixed fuel or not main fuel as required by the electricity
system and market operating Unit to ensure the security of electricity system,
such transaction cycles are paid at the price of power in the electricity sale
contract signed with the single wholesaling Units corresponding to the
configuration of generating set upon operation with single cycle or operation
with mixed fuel or not main fuel.
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10. Where the generating sets have an
approved plan for stop of operation but still have to generate their capacity
at the request of the electricity system and market operating Unit to ensure
the security of electricity system, such power plant shall be separated totally
from the electricity market during the time of capacity generation at the
request of the electricity system and market operating Unit. The total generated
capacity of the plant to the grid during such period of time shall be paid at
the electricity price specified in the electricity sale contract signed with
the single wholesaling Units .
11. Where the power plants with generating
sets separated from grid for independent generation at the request of the electricity
system and market operating Unit, the total power output of such plants in
relevant transaction cycles shall be paid at the electricity price specified in
the electricity sale contract signed with the single wholesaling Units .
12. Where the power plants with generating
sets separated from the national electricity system and connected to the power
grid purchased from foreign country, the total power output of such power
plants in transaction days shall be paid at the electricity price specified in
the electricity sale contract signed with the single wholesaling Units .
13. Where the hydroelectric generating sets
must generate their capacity greater than the announced capacity in the
quotation of next days at the request of the electricity system and market
operating Unit because of security of electricity system, the total generated
output of the power plants to the grid during such period of time shall be paid
at the electricity price specified in the electricity sale contract signed with
the single wholesaling Units .
14. Where the hydropower plants participate
in adjusting level 1 frequency at the request of the electricity system and
market operating Unit, the total generated output of such plants in relevant
cycles shall be paid as per the mechanism of hydropower plants having
reservoirs with regulation capability of less than 02 days, not taking in
account the power output generated for difference compared with dispatching
order (Qdu=0). The hydropower plants of the same group with the ladder
hydropower plants (if any) of the plants participating in level 1 frequency
modulation shall be paid as per the mechanism of hydropower plants having
reservoirs with regulation capability of less than 02 days, taking in account
the power output generated for difference compared with dispatching order.
Section 5: ORDER AND
PAYMENT PROCEDURES
Article 81. Data for
calculation and payment for electricity market
Before 9:00 am of day D+2, the electricity
system and market operating Unit shall aggregate and provide the single
wholesaling Units and the electricity generating Units with data for
calculation and payment for each power plant under the provisions specified in
Annex 6 of this Circular.
Article 82.
Electricity market payment list for transaction days
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2. Before day D+6, the electricity generating
Units directly doing transactions and the single wholesaling Units shall
confirm the electricity market payment list under regulations on the website of
electricity market and inform the electricity system and market operating Unit
of errors in the preliminary electricity market payment list (if any).
3. On day D+6, the electricity system and
market operating Unit shall prepare and send the single wholesaling Units and
the electricity generating Units the complete electricity market payment list
for day D via the website of electricity market under the form specified in
Annex 4 of this Circular. The electricity generating Units shall issue the
daily payment list and file it in dossier for payment for payment cycle.
Article 83.
Electricity market payment list for payment cycle
1. The electricity system and market
operating Unit shall aggregate the payment data for all transaction days in the
payment cycle and verify and compare it with the summary record of power output
provided by the power metering managing Units.
2. Within 10 working days from the last
transaction day of the payment cycle, the electricity system and market
operating Unit shall prepare and issue the electricity market payment list for
payment cycle.
3. The electricity system and market
operating Unit shall prepare and issue the electricity market payment list of
the payment cycle to the single wholesaling Units and the electricity
generating Units.
4. The electricity market payment list for
the payment cycle consists of a summary under the form specified in Annex 5 of
this Circular and a written confirmation of meter readings and power output
Article 84. Dossier
of power dossier
1. The electricity generating Units directly
doing transaction shall prepare and send the payment voucher of electricity
market to the single wholesaling Units based on the electricity market payment
list for the payment cycle.
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3. Before the 20th date of every
month, the electricity generating Units directly doing transaction shall
prepare and send the payment voucher to the single wholesaling Units . Such
voucher consists of payments of electricity market and contract in the payment
cycle.
Article 85. Dossier
payment for auxiliary services supply contract
The electricity generating Units shall
prepare the dossier of payment for auxiliary services under the auxiliary
services supply contract between the electricity generating Units and the electricity
system and market operating Unit.
Article 86. Voucher
modification
1. In case of errors of voucher, the
electricity generating Units or the single wholesaling Units has the right to
request the handling under the relevant current regulations within 01 month
from the issue date. The parties concerned shall coordinate to determine and
agree upon the modified payments.
2. The electricity generating Units shall
supplement the modified payments to the voucher of the next payment cycle.
Article 87. Payment
1. The single wholesaling Units and the electricity
system and market operating Unit shall make payment as per the voucher of the
electricity generating Units. The time limit for payment is based on the
provisions in the electricity sale contract signed between the two parties.
2. The electricity generating Units and the single
wholesaling Units shall agree upon the payment mode in the electricity market
in accordance with the provisions in this Circular and other relevant provisions.
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Article 88. Handling
of errors in payment
In case of surplus or deficit payment
compared with the vouchers, the Units concerned shall handle such errors under
the provisions specified in the electricity sale contract or the auxiliary
service supply contract.
Chapter VII
SOFTWARE
FOR OPERATION OF ELECTRICITY MARKET
Article 89. Software
for operation of electricity market
1. The softwares for operation of electricity
market consist of:
a) Market simulation model;
b) Water value calculating model;
c) Software for mobilization and dispatching
scheduling;
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dd) Other softwares for operation of
electricity market.
2. The electricity system and market
operating Unit shall develop and operate the softwares in service of
electricity market.
Article 90.
Requirements for software for operation of electricity market
1. Ensuring the accuracy, reliability, security
and meeting the standards developed by the electricity system and market
operating Unit.
2. Having all accompanied technical
instructions and operational procedures.
Article 91.
Development of softwares for operation of electricity market
1. The softwares for operation of electricity
market must be developed to support the calculation and transactions specified
in this Circular and the operational procedures of electricity market.
2. The electricity system and market
operating Unit is responsible for
a) Developing standards for the softwares for
the operation of electricity market;
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c) Announcing the list, algorithms and
procedures for using the softwares for the operation of electricity market;
Article 92. Software auditing
1. The softwares for electricity market must
be audited in the following cases:
a) Before the official operation of
electricity market;
b) Before putting the new softwares into use;
c) After adjustment or upgrading affecting
the calculation;
d) Periodical audit.
2. The electricity system and market
operating Unit shall recommend a qualified independent auditing Units to carry
out the audit and report to the Electricity Regulatory Authority before
implementation.
3. The electricity system and market
operating Unit shall announce the auditing result to the participants of
electricity market.
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ELECTRICITY
MARKET INFORMATION SYSTEM AND REGULATIONS ON INFORMATION ANNOUNCEMENT
Section 1:
ELECTRICITY MARKET INFORMATION SYSTEM
Article 93. Structure
of electricity market information system
The electricity market information system
consists of the following basic components:
1. System of hardwares and softwares for
management and exchange of information about electricity market.
2. System of database and storage
3. Web portal in service of electricity
market, including the intranet and public websites.
Article 94. Management
and operation of electricity market information system
1. The electricity system and market
operating Unit shall develop, manage and operate the electricity market
information system.
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3. The power metering data managing Units
shall develop, manage and operate the transmission network connected between
the electricity market information system of the electricity system and market
operating Unit and the equipment of participants of electricity market.
4. The electricity system and market
operating Unit only operates or changes the existing electricity market
information system after complete acceptance and with the approval of the
Electricity Regulatory Authority.
5. The electricity system and market
operating Unit shall equip with backup equipment for the electricity market
information system to ensure the collection, transmission and announcement of
electricity market in case the electricity market information system has
problems or does not work.
Section 2: MANAGEMENT
AND ANNOUNCEMENT OF ELECTRICITY MARKET INFORMATION
Supply and
announcement of electricity market information
1. The electricity generating Units, the
single wholesaling Units, the electricity transmitting Units and the power
metering data managing Units shall provide the electricity system and market
operating Unit with information and data for planning the operation,
mobilization scheduling, calculation and payment under the provisions in this
Circular via the website of electricity market information system.
2. The electricity system and market
operating Unit shall provide and announce information, data and reports on operation
of electricity market to the participants of electricity market under the
provisions in this Circular via the website of the electricity market
information system.
3. The extent of information access right is
defined according to the functions of units and specified in the Procedures for
operational management of information technology system operating the
electricity market and announcement of electricity market information issued by
the Electricity Regulatory Authority.
4. The electricity system and market
operating Unit shall publicly announce on public websites the following
information:
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b) Data of system load;
c) Statiscal data of market price;
d) Other information specified in the
Procedures for operational management of information technology system
operating the electricity market and announcement of electricity market
information issued by the Electricity Regulatory Authority.
Article 96. Responsibility
for ensuring the accuracy of electricity market information
1. Members participating in electricity
market must ensure the accuracy and accuracy of electricity market information
at the time of supply.
2. In case of detection of information
inaccurately and incompletely provided or announced, the members participating
in electricity market shall modify and re-supply correct information to the
concerned units.
Article 97. Electricity
market information security
1. The electricity system and market
operating Unit must not disclose information provided by the participants of
electricity market, including:
a) Information about electricity sale
contract;
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c) Other information beyond authority
2. The participants of electricity market must
not disclose information beyond the scope of authority given to provide and
announce information.
Article 98. Cases of
immunity from information security
1. Provision of information at the request of
the Electricity Regulatory Authority or the competent authorities under
regulation of law.
2. The information self summarized or
analyzed from information announced in the electricity market, not provided
improperly from other participants of electricity market specified in Article
97 of this Circular.
Article 99. Storage
of electricity market information
The electricity system and market operating
Unit is responsible for storing all activities of information exchange to be
done via the electricity market information system. The duration
of
storage of
information is at least 05 years.
Section 3: REPORT ON
ELECTRICITY MARKET OPERATION
Article 100. Announcement
of information about operation of electricity market
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1. Before 15:00 pm of every day, preparing
and announcing the electricity market operation report of the previous day.
2. Before 16:00 pm of Tuesdays of every week,
preparing and announcing the electricity market operation report of the
previous week.
3. Before the 10th date of every
month, preparing and announcing the electricity market operation report of the
previous month.
4. Before the 31st date of January
of every year, preparing and announcing the electricity market operation report
of the previous year.
Article 101. Regulation
on electricity market operation report
1. Before the 10th date of every
month, the electricity system and market operating Unit shall send the
Electricity Regulatory Authority the electricity system and market operating
report of the previous month under the form specified by the Electricity
Regulatory Authority.
2. Before the 31st date of January
of every year, the electricity system and market operating Unit shall send the
Electricity Regulatory Authority the electricity system and market operating
report of the previous year under the form specified by the Electricity
Regulatory Authority.
3. Within 24 hours from the termination of
intervention in electricity market, the electricity system and market operating
Unit shall report to the Electricity Regulatory Authority on the intervention
in electricity market.
4. The electricity system and market
operating Unit shall make unplanned reports on the electricity system and
market operation as required by the Electricity Regulatory Authority.
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1. Periodical audit
Before the 31st date of March of
every year, the electricity system and market operating Unit shall implement
and complete the audit of data and compliance in electricity market of the
previous year. The yearly auditing contents include:
a) Audit of data and calculation process of
the electricity system and market operating Unit in the electricity market:
- Data for calculation process in electricity
market;
- Steps of calculation;
- Result of calculation;
b) Audit of compliance of the electricity
system and market operating Unit for the order and procedures specified in this
Circular.
2. Unplanned audit
The Electricity Regulatory Authority has the
right to require the electricity system and market operating Unit to organize
the implementation of unplanned audit as per the specific contents and scope of
audit in the following cases:
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b) As requested in writing of the
participants of electricity market in which the contents and plausible reasons
to request the unplanned audit.
3. The electricity system and market
operating Unit is responsible for recommending a qualified independent auditing
unit to carry out the auditing contents of electricity market to be submitted
to the Electricity Regulatory Authority for approval.
4. The participants of electricity market
must fully cooperate with one another during the audit of electricity market;
5. Audit expenses
a) To be paid by the electricity system and
market operating Unit in cases of audit specified in Clause 1 and Point a,
Clause 2 of this Article;
b) To be paid the unit requesting audit in
cases of audit specified under Point b, Clause 2 of this Article.
6. Within 10 days after the end of audit, the
electricity system and market operating Unit shall send the auditing report to
the Electricity Regulatory Authority and the related units.
Chapter IX
DISPUTE
SETTLEMENT AND VIOLATION HANDLING
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Article 103. Order
for dispute settlement in electricity market
1. The disputes arising in the electricity
market shall be settled as per the Regulation on order and procedures for
dispute settlement in the electricity market issued by the Ministry of Industry
and Trade.
2. Before carrying out the dispute settlement
under the provisions in Clause 1 of this Article, within 60 days from the time
of arising dispute in electricity market, the parties must conduct the
negotiation to settle their dispute in one of the following forms:
a) Negotiation;
b) Reconciliation.
Article 104. Responsibilities
of parties in self-settlement of dispute
1. Reaching an agreement on the form of
self-settlement of dispute, time and location of negotiation.
2. Fully, honestly and accurately providing
the necessary information and documents related to the contents under dispute.
3. Providing legal evidence to protect legal
rights and interests.
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5. During the process of self-settlement of
dispute, if the dispute is detected to have signs of violating regulations on
electricity market, the detecting party shall notify the other party in order
to stop their self-settlement of dispute and report to the Electricity
Regulatory Authority.
Article 105. Notification
of dispute and negotiation preparation
1. When there is any dispute, the requester
shall notify in writing the requestee of the dispute and request the dispute
settlement and send 01 (one) copy to the Electricity Regulatory Authority for
report.
2. Within 15 days from the receipt of
notification, the parties must agree upon the form of dispute settlement,
contents to be settled, time and location of negotiation. In case of choice of
form of reconciliation through intermediary,
the parties must agree upon choosing the intermediary. The parties may agree
upon the change of intermediary before the estimated time of reconciliation
agreed.
Article 106. Organization
of self-settlement of dispute
1. Negotiation
The parties shall discuss and agree upon the
contents to be settled.
2. Reconciliation
a) The parties may invite experts or request
the Electricity Regulatory Authority to appoint its official to be the
intermediary and agree upon the responsibility of intermediary;
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c) The parties may agree with the settlement
plan of the intermediary; request the intermediary to modify or supplement such
settlement plan or agree by themselves with the new settlement plan.
Article 107. Record
of self-settlement of dispute
1. After the end of self-settlement of
dispute or the end of time limit for self-settlement of dispute, the disputing
parties shall make a record of self-settlement of dispute including the
following contents:
a) Time and location for self-settlement of
dispute;
b) Name and address of parties involved in
self-settlement of dispute;
c) Summary of dispute contents;
d) Requirements of the parties;
dd) Contents agreed by the parties;
e) Contents the parties fail to agree upon
and reasons for failure
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Article 108. Dispute
settlement at the Electricity Regulatory Authority
1. The parties have their right to refer the
case to the Electricity Regulatory Authority for settlement in the following
cases:
a) Upon the end of time limit for
self-settlement of dispute specified in Clause 2, Article 103 of this Circular
but the dispute cannot be settled or the self-settlement of dispute cannot be
held because one party does not participate in the self-settlement of dispute.
b) One party does not adhere to the contents
agreed in the Record of the self-settlement of dispute.
2. After receiving the valid dossier for
dispute settlement under regulations, the Electricity Regulatory Authority
shall settle it in the order and procedures specified in the Regulation on
order and procedures for dispute settlement in the electricity market which the
Ministry of Industry and Trade has issued.
Section 2 :
VIOLATION HANDLING
Article 109. Violation
detection and report
1. The acts of violation in the electricity
market detected must be reported to the Electricity Regulatory Authority in
writing.
2. The contents of report include:
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b) Name, address of organization or
individual making report;
c) Name, address of organization or individual
committing acts with violating signs;
d) Description of acts with violating signs;
dd) Time and location of occurrence of acts
with violating signs;
e) Reasons for detecting acts with violating
signs (if any).
Article 110. Verification
of acts of violation
1. Within 05 days from the date of receipt of
case concerning acts with violating signs, the Electricity Regulatory Authority
shall handle the case and shall inform in writing to the reporting organization
or individual in case of failure to handle.
2. After handling the case, the Electricity
Regulatory Authority shall verify the acts with violating signs. During the
verification, the Electricity Regulatory Authority has the right to:
a) Require the unit with violating signs and
the units concerned to provide information and documents necessary for the
verification;
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c) Hold an expertise and gather opinions from
specialist or agencies or units concerned.
d) Convene the unit with violating signs and
the units affected due to violating acts for opinions about the way of
settlement and remedy of violating acts.
3. During the verification, the Electricity
Regulatory Authority must maintaining the
confidentiality of the information and
materials
provided
under the regulations on information security specified in this Circular and
other legal regulations related to the confidentiality of
the
information.
Article 111. Making
record of administrative violation
1. Within 60 working days from the date of verification,
the Electricity Regulatory Authority shall terminate the verification and make
record of administrative violation for violating acts of regulation on
operation of electricity market. If the case has complicated details, the
verification time may be extended but not exceeding 30 working days from the
end date of verification.
2. The record of administrative violation is
made under regulation on sanctioning of admnistrative violation in the field of
electricity.
3. If the result of verification indicates
that the reported acts do not violate the regulations on operation of
electricity market, the Electricity Regulatory Authority shall stop its
verification and notify the reporting organization or individual as well as the
verified organization or individual.
Article 112. Forms of
handling of violation
1. The violating unit must undergo one of the
form or degree of sanction for each violating act specified in Article 14 of
Decree No. 134/2013/ND-CP dated 17 October 2013 stipulating the sanction of administrative
violation in the field of electricity, safety of hydroelectric dam, thrifty and
effective use of energy.
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Article 113. Order
and procedures for suspending the right to participate in electricity market
1. Where the power plants commit violating
acts specified in Clause 1, Article 8 of this Circular, within 05 (five) days
from the date of issuing Decision on sanction of administrative violation or
from the date of issuing the written conclusion on violating acts causing
serious consequences on security of power supply or finance to other units in
the electricity market, the Electricity Regulatory Authority shall review and
issue a decision on suspending the right to participate in electricity market
to the power plants committing the violating acts and send it to the violating
power plant and the electricity system and market operating Unit.
2. The effective
duration
of
the
decision
on suspending the right to participate
in the electricity market to the power plants committing the violating
acts is more than
01 (one) year.
3. Within 01 from the date of receiving the
Decision on suspending the
right to
participate
in the electricity market, the electricity system and market operating Unit shall
announce such suspension to the violating power plant.
4. If the time limit specified in Clause 2 of
this Article is over, such power plant has not remedied its violation, the
Electricity Regulatory Authority has the right to extend such suspension.
Chapter X
IMPLEMENTATION
Article 114. Responsibility
of the Electricity Regulatory Authority
1. Disseminating, inspecting and monitoring
the implementation of this Circular.
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Article 115. Responsibility
of Vietnam Electricity
The Vietnam Electricity shall direct
the electricity system and market operating Unit and the related units:
1. Reviewing and modifying the technical
procedures to be submitted to the Electricity Regulatory Authority for issuance
after 30 days from the date of issue:
a) Procedures for planning operation of next
year, month and week;
b) Procedures for choosing the best new power
plant and calculating the price of market capacity;
c) Procedures for electricity market
simulation;
d) Procedures for calculation of water value;
dd) Procedures for classifying the generating
set and calculating the price ceiling of quotation of thermal power plants;
e) Procedures for mobilization scheduling of
generating sets, real-time operation and calculation and payment in electricity
market;
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h) Procedures for coordinated comparison and
review of payment data between the electricity system and market operating
Unit, the electricity generating Units and the single wholesaling Units;
i) Procedures for registration of
participation in electricity market;
k) Procedures for optimal use of gas fuel
resources for mobilization schedule of next days;
l) Procedures for
coordinated confirmation of events for payments in the electricity market.
2. Investing, building, installing and
upgrading the electricity market information System and the softwares in
service of electricity market in accordance with requirements specified in this
Circular.
Article 116. Responsibility
of related units
1. The units participating in the electricity
market must improve the information equipment in accordance with the
electricity market information System under the provisions specified in this
Circular.
2. The electricity generating Units
participating in the electricity market must sign the electricity sale
contracts under the form issued by the Ministry of Industry and Trade for
application to the electricity market.
Article 117. Effect
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Any problem arising during the implementation
should be promptly reported to the Electricity Regulatory Authority for
submission to the Ministry of Industry and Trade for admendment or supplement
accordingly.
The related units must carry out the
instructions under the provisions specified in Clause 2, Article 114 to the
time of issuance of amended or supplemented Circular.
FOR THE MINISTER
DEPUTY MINISTER
Cao Quoc Hung